FERC Form

THIS FILING IS

Item 1:

☑ An Initial (Original) Submission

OR

☐ Resubmission No.




FERC FINANCIAL REPORT FERC FORM No. 1: Annual Report of Major Electric Utilities, Licensees and Others and Supplemental Form 3-Q: Quarterly Financial Report

These reports are mandatory under the Federal Power Act, Sections 3, 4(a), 304 and 309, and 18 CFR 141.1 and 141.400. Failure to report may result in criminal fines, civil penalties and other sanctions as provided by law. The Federal Energy Regulatory Commission does not consider these reports to be of confidential nature

Exact Legal Name of Respondent (Company)

Entergy Mississippi, LLC

Year/Period of Report

End of:

2021

/

Q4

INSTRUCTIONS FOR FILING FERC FORM NOS. 1 and 3-Q

GENERAL INFORMATION

Purpose
FERC Form No. 1 (FERC Form 1) is an annual regulatory requirement for Major electric utilities, licensees and others (18 C.F.R. § 141.1). FERC Form No. 3-Q ( FERC Form 3-Q) is a quarterly regulatory requirement which supplements the annual financial reporting requirement (18 C.F.R. § 141.400). These reports are designed to collect financial and operational information from electric utilities, licensees and others subject to the jurisdiction of the Federal Energy Regulatory Commission. These reports are also considered to be non-confidential public use forms.
Who Must Submit
Each Major electric utility, licensee, or other, as classified in the Commission’s Uniform System of Accounts Prescribed for Public Utilities, Licensees, and Others Subject To the Provisions of The Federal Power Act (18 C.F.R. Part 101), must submit FERC Form 1 (18 C.F.R. § 141.1), and FERC Form 3-Q (18 C.F.R. § 141.400).
Note: Major means having, in each of the three previous calendar years, sales or transmission service that exceeds one of the following:
1. one million megawatt hours of total annual sales,
2. 100 megawatt hours of annual sales for resale,
3. 500 megawatt hours of annual power exchanges delivered, or
4. 500 megawatt hours of annual wheeling for others (deliveries plus losses).

What and Where to Submit

Submit FERC Form Nos. 1 and 3-Q electronically through the eCollection portal at https://eCollection.ferc.gov, and according to the specifications in the Form 1 and 3-Q taxonomies.
The Corporate Officer Certification must be submitted electronically as part of the FERC Forms 1 and 3-Q filings.
Submit immediately upon publication, by either eFiling or mail, two (2) copies to the Secretary of the Commission, the latest Annual Report to Stockholders. Unless eFiling the Annual Report to Stockholders, mail the stockholders report to the Secretary of the Commission at:
Secretary
Federal Energy Regulatory Commission 888 First Street, NE
Washington, DC 20426

For the CPA Certification Statement, submit within 30 days after filing the FERC Form 1, a letter or report (not applicable to filers classified as Class C or Class D prior to January 1, 1984). The CPA Certification Statement can be either eFiled or mailed to the Secretary of the Commission at the address above.

The CPA Certification Statement should:

Attest to the conformity, in all material aspects, of the below listed (schedules and pages) with the Commission's applicable Uniform System of Accounts (including applicable notes relating thereto and the Chief Accountant's published accounting releases), and

Be signed by independent certified public accountants or an independent licensed public accountant certified or licensed by a regulatory authority of a State or other political subdivision of the U. S. (See 18 C.F.R. §§ 41.10-41.12 for specific qualifications.)

Schedules	Pages
Comparative Balance Sheet	110-113
Statement of Income	114-117
Statement of Retained Earnings	118-119
Statement of Cash Flows	120-121
Notes to Financial Statements	122-123

The following format must be used for the CPA Certification Statement unless unusual circumstances or conditions, explained in the letter or report, demand that it be varied. Insert parenthetical phrases only when exceptions are reported.
“In connection with our regular examination of the financial statements of [COMPANY NAME] for the year ended on which we have reported separately under date of [DATE], we have also reviewed schedules [NAME OF SCHEDULES] of FERC Form No. 1 for the year filed with the Federal Energy Regulatory Commission, for conformity in all material respects with the requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases. Our review for this purpose included such tests of the accounting records and such other auditing procedures as we considered necessary in the circumstances.
Based on our review, in our opinion the accompanying schedules identified in the preceding paragraph (except as noted below) conform in all material respects with the accounting requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases.” The letter or report must state which, if any, of the pages above do not conform to the Commission’s requirements. Describe the discrepancies that exist.
Filers are encouraged to file their Annual Report to Stockholders, and the CPA Certification Statement using eFiling. Further instructions are found on the Commission’s website at https://www.ferc.gov/ferc-online/ferc-online/frequently-asked-questions-faqs-efilingferc-online.
Federal, State, and Local Governments and other authorized users may obtain additional blank copies of FERC Form 1 and 3-Q free of charge from https://www.ferc.gov/general-information-0/electric-industry-forms.

When to Submit
FERC Forms 1 and 3-Q must be filed by the following schedule:
1. FERC Form 1 for each year ending December 31 must be filed by April 18th of the following year (18 CFR § 141.1), and
2. FERC Form 3-Q for each calendar quarter must be filed within 60 days after the reporting quarter (18 C.F.R. § 141.400).
Where to Send Comments on Public Reporting Burden.
The public reporting burden for the FERC Form 1 collection of information is estimated to average 1,168 hours per response, including the time for reviewing instructions, searching existing data sources, gathering and maintaining the data-needed, and completing and reviewing the collection of information. The public reporting burden for the FERC Form 3-Q collection of information is estimated to average 168 hours per response.
Send comments regarding these burden estimates or any aspect of these collections of information, including suggestions for reducing burden, to the Federal Energy Regulatory Commission, 888 First Street NE, Washington, DC 20426 (Attention: Information Clearance Officer); and to the Office of Information and Regulatory Affairs, Office of Management and Budget, Washington, DC 20503 (Attention: Desk Officer for the Federal Energy Regulatory Commission). No person shall be subject to any penalty if any collection of information does not display a valid control number (44 U.S.C. § 3512 (a)).

GENERAL INSTRUCTIONS

Prepare this report in conformity with the Uniform System of Accounts (18 CFR Part 101) (USofA). Interpret all accounting words and phrases in accordance with the USofA.
Enter in whole numbers (dollars or MWH) only, except where otherwise noted. (Enter cents for averages and figures per unit where cents are important. The truncating of cents is allowed except on the four basic financial statements where rounding is required.) The amounts shown on all supporting pages must agree with the amounts entered on the statements that they support. When applying thresholds to determine significance for reporting purposes, use for balance sheet accounts the balances at the end of the current reporting period, and use for statement of income accounts the current year's year to date amounts.
Complete each question fully and accurately, even if it has been answered in a previous report. Enter the word "None" where it truly and completely states the fact.
For any page(s) that is not applicable to the respondent, omit the page(s) and enter "NA," "NONE," or "Not Applicable" in column (d) on the List of Schedules, pages 2 and 3.
Enter the month, day, and year for all dates. Use customary abbreviations. The "Date of Report" included in the header of each page is to be completed only for resubmissions (see VII. below).
Generally, except for certain schedules, all numbers, whether they are expected to be debits or credits, must be reported as positive. Numbers having a sign that is different from the expected sign must be reported by enclosing the numbers in parentheses.
For any resubmissions, please explain the reason for the resubmission in a footnote to the data field.
Do not make references to reports of previous periods/years or to other reports in lieu of required entries, except as specifically authorized.
Wherever (schedule) pages refer to figures from a previous period/year, the figures reported must be based upon those shown by the report of the previous period/year, or an appropriate explanation given as to why the different figures were used.
Schedule specific instructions are found in the applicable taxonomy and on the applicable blank rendered form.

Definitions for statistical classifications used for completing schedules for transmission system reporting are as follows:

FNS - Firm Network Transmission Service for Self. "Firm" means service that can not be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Network Service" is Network Transmission Service as described in Order No. 888 and the Open Access Transmission Tariff. "Self" means the respondent.

FNO - Firm Network Service for Others. "Firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Network Service" is Network Transmission Service as described in Order No. 888 and the Open Access Transmission Tariff.

LFP - for Long-Term Firm Point-to-Point Transmission Reservations. "Long-Term" means one year or longer and” firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Point-to-Point Transmission Reservations" are described in Order No. 888 and the Open Access Transmission Tariff. For all transactions identified as LFP, provide in a footnote the termination date of the contract defined as the earliest date either buyer or seller can unilaterally cancel the contract.

OLF - Other Long-Term Firm Transmission Service. Report service provided under contracts which do not conform to the terms of the Open Access Transmission Tariff. "Long-Term" means one year or longer and “firm” means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. For all transactions identified as OLF, provide in a footnote the termination date of the contract defined as the earliest date either buyer or seller can unilaterally get out of the contract.

SFP - Short-Term Firm Point-to-Point Transmission Reservations. Use this classification for all firm point-to-point transmission reservations, where the duration of each period of reservation is less than one-year.

NF - Non-Firm Transmission Service, where firm means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions.

OS - Other Transmission Service. Use this classification only for those services which can not be placed in the above-mentioned classifications, such as all other service regardless of the length of the contract and service FERC Form. Describe the type of service in a footnote for each entry.

AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment.

DEFINITIONS

Commission Authorization (Comm. Auth.) -- The authorization of the Federal Energy Regulatory Commission, or any other Commission. Name the commission whose authorization was obtained and give date of the authorization.
Respondent -- The person, corporation, licensee, agency, authority, or other Legal entity or instrumentality in whose behalf the report is made.

EXCERPTS FROM THE LAW

Federal Power Act, 16 U.S.C. § 791a-825r

Sec. 3. The words defined in this section shall have the following meanings for purposes of this Act, to with:

’Corporation' means any corporation, joint-stock company, partnership, association, business trust, organized group of persons, whether incorporated or not, or a receiver or receivers, trustee or trustees of any of the foregoing. It shall not include 'municipalities, as hereinafter defined;
'Person' means an individual or a corporation;
'Licensee, means any person, State, or municipality Licensed under the provisions of section 4 of this Act, and any assignee or successor in interest thereof;

'municipality means a city, county, irrigation district, drainage district, or other political subdivision or agency of a State competent under the Laws thereof to carry and the business of developing, transmitting, unitizing, or distributing power; ......

"project' means. a complete unit of improvement or development, consisting of a power house, all water conduits, all dams and appurtenant works and structures (including navigation structures) which are a part of said unit, and all storage, diverting, or fore bay reservoirs directly connected therewith, the primary line or lines transmitting power there from to the point of junction with the distribution system or with the interconnected primary transmission system, all miscellaneous structures used and useful in connection with said unit or any part thereof, and all water rights, rights-of-way, ditches, dams, reservoirs, Lands, or interest in Lands the use and occupancy of which are necessary or appropriate in the maintenance and operation of such unit;

"Sec. 4. The Commission is hereby authorized and empowered

'To make investigations and to collect and record data concerning the utilization of the water 'resources of any region to be developed, the water-power industry and its relation to other industries and to interstate or foreign commerce, and concerning the location, capacity, development costs, and relation to markets of power sites; ... to the extent the Commission may deem necessary or useful for the purposes of this Act."

"Sec. 304.

Every Licensee and every public utility shall file with the Commission such annual and other periodic or special* reports as the Commission may by rules and regulations or other prescribe as necessary or appropriate to assist the Commission in the proper administration of this Act. The Commission may prescribe the manner and FERC Form in which such reports shall be made, and require from such persons specific answers to all questions upon which the Commission may need information. The Commission may require that such reports shall include, among other things, full information as to assets and Liabilities, capitalization, net investment, and reduction thereof, gross receipts, interest due and paid, depreciation, and other reserves, cost of project and other facilities, cost of maintenance and operation of the project and other facilities, cost of renewals and replacement of the project works and other facilities, depreciation, generation, transmission, distribution, delivery, use, and sale of electric energy. The Commission may require any such person to make adequate provision for currently determining such costs and other facts. Such reports shall be made under oath unless the Commission otherwise specifies*.10

"Sec. 309.

The Commission shall have power to perform any and all acts, and to prescribe, issue, make, and rescind such orders, rules and regulations as it may find necessary or appropriate to carry out the provisions of this Act. Among other things, such rules and regulations may define accounting, technical, and trade terms used in this Act; and may prescribe the FERC Form or FERC Forms of all statements, declarations, applications, and reports to be filed with the Commission, the information which they shall contain, and the time within which they shall be field..."

GENERAL PENALTIES

The Commission may assess up to $1 million per day per violation of its rules and regulations. See FPA § 316(a) (2005), 16 U.S.C. § 825o(a).

FERC FORM NO.

1

REPORT OF MAJOR ELECTRIC UTILITIES, LICENSEES AND OTHER

IDENTIFICATION

01 Exact Legal Name of Respondent

Entergy Mississippi, LLC

02 Year/ Period of Report

End of:

2021

/

Q4

03 Previous Name and Date of Change (If name changed during year)

/

04 Address of Principal Office at End of Period (Street, City, State, Zip Code)

308 East Pearl Street, Jackson, Mississippi 39201

05 Name of Contact Person

Gina G. Bellott

06 Title of Contact Person

Sr. Staff Accountant

07 Address of Contact Person (Street, City, State, Zip Code)

639 Loyola Avenue, New Orleans, Louisiana 70113

08 Telephone of Contact Person, Including Area Code

(504) 858-3276

09 This Report is An Original / A Resubmission

(1)

☑ An Original

(2)

☐ A Resubmission

10 Date of Report (Mo, Da, Yr)

04/15/2022

Annual Corporate Officer Certification

The undersigned officer certifies that:

I have examined this report and to the best of my knowledge, information, and belief all statements of fact contained in this report are correct statements of the business affairs of the respondent and the financial statements, and other financial information contained in this report, conform in all material respects to the Uniform System of Accounts.

01 Name

Kimberly A. Fontan

02 Title

Sr VP & Chief Accounting Officer

03 Signature

Kimberly A. Fontan

04 Date Signed (Mo, Da, Yr)

04/15/2022

Title 18, U.S.C. 1001 makes it a crime for any person to knowingly and willingly to make to any Agency or Department of the United States any false, fictitious or fraudulent statements as to any matter within its jurisdiction.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

LIST OF SCHEDULES (Electric Utility)
Enter in column (c) the terms "none," "not applicable," or "NA," as appropriate, where no information or amounts have been reported for certain pages. Omit pages where the respondents are "none," "not applicable," or "NA".
Line No.	Title of Schedule (a)	Reference Page No. (b)	Remarks (c)
	ScheduleIdentificationAbstract Identification	1
	ScheduleListOfSchedulesAbstract List of Schedules	2
1	ScheduleGeneralInformationAbstract General Information	101
2	ScheduleControlOverRespondentAbstract Control Over Respondent	102
3	ScheduleCorporationsControlledByRespondentAbstract Corporations Controlled by Respondent	103
4	ScheduleOfficersAbstract Officers	104
5	ScheduleDirectorsAbstract Directors	105
6	ScheduleInformationOnFormulaRatesAbstract Information on Formula Rates	106
7	ScheduleImportantChangesDuringTheQuarterYearAbstract Important Changes During the Year	108
8	ScheduleComparativeBalanceSheetAbstract Comparative Balance Sheet	110
9	ScheduleStatementOfIncomeAbstract Statement of Income for the Year	114
10	ScheduleRetainedEarningsAbstract Statement of Retained Earnings for the Year	118
12	ScheduleStatementOfCashFlowsAbstract Statement of Cash Flows	120
12	ScheduleNotesToFinancialStatementsAbstract Notes to Financial Statements	122
13	ScheduleStatementOfAccumulatedOtherComprehensiveIncomeAndHedgingActivitiesAbstract Statement of Accum Other Comp Income, Comp Income, and Hedging Activities	122a	NA
14	ScheduleSummaryOfUtilityPlantAndAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract Summary of Utility Plant & Accumulated Provisions for Dep, Amort & Dep	200
15	ScheduleNuclearFuelMaterialsAbstract Nuclear Fuel Materials	202	NA
16	ScheduleElectricPlantInServiceAbstract Electric Plant in Service	204
17	ScheduleElectricPropertyLeasedToOthersAbstract Electric Plant Leased to Others	213	NA
18	ScheduleElectricPlantHeldForFutureUseAbstract Electric Plant Held for Future Use	214
19	ScheduleConstructionWorkInProgressElectricAbstract Construction Work in Progress-Electric	216
20	ScheduleAccumulatedProvisionForDepreciationOfElectricUtilityPlantAbstract Accumulated Provision for Depreciation of Electric Utility Plant	219
21	ScheduleInvestmentsInSubsidiaryCompaniesAbstract Investment of Subsidiary Companies	224
22	ScheduleMaterialsAndSuppliesAbstract Materials and Supplies	227
23	ScheduleAllowanceInventoryAbstract Allowances	228
24	ScheduleExtraordinaryPropertyLossesAbstract Extraordinary Property Losses	230a	NA
25	ScheduleUnrecoveredPlantAndRegulatoryStudyCostsAbstract Unrecovered Plant and Regulatory Study Costs	230b	NA
26	ScheduleTransmissionServiceAndGenerationInterconnectionStudyCostsAbstract Transmission Service and Generation Interconnection Study Costs	231	NA
27	ScheduleOtherRegulatoryAssetsAbstract Other Regulatory Assets	232
28	ScheduleMiscellaneousDeferredDebitsAbstract Miscellaneous Deferred Debits	233
29	ScheduleAccumulatedDeferredIncomeTaxesAbstract Accumulated Deferred Income Taxes	234
30	ScheduleCapitalStockAbstract Capital Stock	250	NA
31	ScheduleOtherPaidInCapitalAbstract Other Paid-in Capital	253
32	ScheduleCapitalStockExpenseAbstract Capital Stock Expense	254b	NA
33	ScheduleLongTermDebtAbstract Long-Term Debt	256
34	ScheduleReconciliationOfReportedNetIncomeWithTaxableIncomeForFederalIncomeTaxesAbstract Reconciliation of Reported Net Income with Taxable Inc for Fed Inc Tax	261
35	ScheduleTaxesAccruedPrepaidAndChargedDuringYearDistributionOfTaxesChargedAbstract Taxes Accrued, Prepaid and Charged During the Year	262
36	ScheduleAccumulatedDeferredInvestmentTaxCreditsAbstract Accumulated Deferred Investment Tax Credits	266
37	ScheduleOtherDeferredCreditsAbstract Other Deferred Credits	269
38	ScheduleAccumulatedDeferredIncomeTaxesAcceleratedAmortizationPropertyAbstract Accumulated Deferred Income Taxes-Accelerated Amortization Property	272	NA
39	ScheduleAccumulatedDeferredIncomeTaxesOtherPropertyAbstract Accumulated Deferred Income Taxes-Other Property	274
40	ScheduleAccumulatedDeferredIncomeTaxesOtherAbstract Accumulated Deferred Income Taxes-Other	276
41	ScheduleOtherRegulatoryLiabilitiesAbstract Other Regulatory Liabilities	278
42	ScheduleElectricOperatingRevenuesAbstract Electric Operating Revenues	300
43	ScheduleRegionalTransmissionServiceRevenuesAbstract Regional Transmission Service Revenues (Account 457.1)	302
44	ScheduleSalesOfElectricityByRateSchedulesAbstract Sales of Electricity by Rate Schedules	304
45	ScheduleSalesForResaleAbstract Sales for Resale	310
46	ScheduleElectricOperationsAndMaintenanceExpensesAbstract Electric Operation and Maintenance Expenses	320
47	SchedulePurchasedPowerAbstract Purchased Power	326
48	ScheduleTransmissionOfElectricityForOthersAbstract Transmission of Electricity for Others	328
49	ScheduleTransmissionOfElectricityByIsoOrRtoAbstract Transmission of Electricity by ISO/RTOs	331	NA
50	ScheduleTransmissionOfElectricityByOthersAbstract Transmission of Electricity by Others	332
51	ScheduleMiscellaneousGeneralExpensesAbstract Miscellaneous General Expenses-Electric	335
52	ScheduleDepreciationDepletionAndAmortizationAbstract Depreciation and Amortization of Electric Plant (Account 403, 404, 405)	336
53	ScheduleRegulatoryCommissionExpensesAbstract Regulatory Commission Expenses	350
54	ScheduleResearchDevelopmentOrDemonstrationExpendituresAbstract Research, Development and Demonstration Activities	352
55	ScheduleDistributionOfSalariesAndWagesAbstract Distribution of Salaries and Wages	354
56	ScheduleCommonUtilityPlantAndExpensesAbstract Common Utility Plant and Expenses	356	NA
57	ScheduleAmountsIncludedInIsoOrRtoSettlementAbstract Amounts included in ISO/RTO Settlement Statements	397
58	SchedulePurchasesSalesOfAncillaryServicesAbstract Purchase and Sale of Ancillary Services	398
59	ScheduleMonthlyTransmissionSystemPeakLoadAbstract Monthly Transmission System Peak Load	400
60	ScheduleMonthlyIsoOrRtoTransmissionSystemPeakLoadAbstract Monthly ISO/RTO Transmission System Peak Load	400a	NA
61	ScheduleElectricEnergyAccountAbstract Electric Energy Account	401a
62	ScheduleMonthlyPeakAndOutputAbstract Monthly Peaks and Output	401b
63	ScheduleSteamElectricGeneratingPlantStatisticsAbstract Steam Electric Generating Plant Statistics	402
64	ScheduleHydroelectricGeneratingPlantStatisticsAbstract Hydroelectric Generating Plant Statistics	406	NA
65	SchedulePumpedStorageGeneratingPlantStatisticsAbstract Pumped Storage Generating Plant Statistics	408	NA
66	ScheduleGeneratingPlantStatisticsAbstract Generating Plant Statistics Pages	410	NA
0	ScheduleEnergyStorageOperationsLargePlantsAbstract Energy Storage Operations (Large Plants)	414	NA
67	ScheduleTransmissionLineStatisticsAbstract Transmission Line Statistics Pages	422
68	ScheduleTransmissionLinesAddedAbstract Transmission Lines Added During Year	424
69	ScheduleSubstationsAbstract Substations	426
70	ScheduleTransactionsWithAssociatedAffiliatedCompaniesAbstract Transactions with Associated (Affiliated) Companies	429
71	FootnoteDataAbstract Footnote Data	450	NA
	StockholdersReportsAbstract Stockholders' Reports (check appropriate box)
	Stockholders' Reports Check appropriate box: ☐ Two copies will be submitted ☑ No annual report to stockholders is prepared

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

GENERAL INFORMATION
1. Provide name and title of officer having custody of the general corporate books of account and address of office where the general corporate books are kept, and address of office where any other corporate books of account are kept, if different from that where the general corporate books are kept. Kimberly A. Fontan Senior Vice President and Chief Accounting Officer 639 Loyola Avenue, New Orleans, LA 70113
2. Provide the name of the State under the laws of which respondent is incorporated, and date of incorporation. If incorporated under a special law, give reference to such law. If not incorporated, state that fact and give the type of organization and the date organized. State of Incorporation: TX Date of Incorporation: 2018-09-17 Incorporated Under Special Law:
3. If at any time during the year the property of respondent was held by a receiver or trustee, give (a) name of receiver or trustee, (b) date such receiver or trustee took possession, (c) the authority by which the receivership or trusteeship was created, and (d) date when possession by receiver or trustee ceased. N/A (a) Name of Receiver or Trustee Holding Property of the Respondent: (b) Date Receiver took Possession of Respondent Property: (c) Authority by which the Receivership or Trusteeship was created: (d) Date when possession by receiver or trustee ceased:
4. State the classes or utility and other services furnished by respondent during the year in each State in which the respondent operated. Mississippi - Electric Utility Service
5. Have you engaged as the principal accountant to audit your financial statements an accountant who is not the principal accountant for your previous year's certified financial statements? (1) ☐ Yes (2) ☑ No

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

CONTROL OVER RESPONDENT
1. If any corporation, business trust, or similar organization or a combination of such organizations jointly held control over the respondent at the end of the year, state name of controlling corporation or organization, manner in which control was held, and extent of control. If control was in a holding company organization, show the chain of ownership or control to the main parent company or organization. If control was held by a trustee(s), state name of trustee(s), name of beneficiary or beneficiaries for whom trust was maintained, and purpose of the trust.

As of December 31, 2021, all of the common membership interests in Entergy Mississippi are held by Entergy Utility Holding Company. As of December 31, 2021, Entergy Utility Holding Company's membership interests are held by: Entergy Corporation 3.5% 386,954 shares Entergy Utility Affiliates 22.2% multiple securities Entergy Utility Assets 29.7% 3,276,704 shares Entergy Utility Enterprises 12.5% 1,381,535 shares Entergy Utility Group 3.2% 350,173 shares Entergy Utility Property 27.2% 3,006,086 shares Unaffiliated third parties 1.7% multiple securities

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

CORPORATIONS CONTROLLED BY RESPONDENT
Report below the names of all corporations, business trusts, and similar organizations, controlled directly or indirectly by respondent at any time during the year. If control ceased prior to end of year, give particulars (details) in a footnote. If control was by other means than a direct holding of voting rights, state in a footnote the manner in which control was held, naming any intermediaries involved. If control was held jointly with one or more other interests, state the fact in a footnote and name the other interests. Definitions See the Uniform System of Accounts for a definition of control. Direct control is that which is exercised without interposition of an intermediary. Indirect control is that which is exercised by the interposition of an intermediary which exercises direct control. Joint control is that in which neither interest can effectively control or direct action without the consent of the other, as where the voting control is equally divided between two holders, or each party holds a veto power over the other. Joint control may exist by mutual agreement or understanding between two or more parties who together have control within the meaning of the definition of control in the Uniform System of Accounts, regardless of the relative voting rights of each party.
Line No.	NameOfCompanyControlledByRespondent Name of Company Controlled (a)	CompanyControlledByRespondentKindOfBusinessDescription Kind of Business (b)	VotingStockOwnedByRespondentPercentage Percent Voting Stock Owned (c)	FootnoteReferences Footnote Ref. (d)
1	EMI New Nuclear, LLC		100
2	Entergy Power & Light Company		100
3	The Light, Heat and Water Company of Jackson, Mississippi		100
4	Jackson Gas Light Company		100
5	Mississippi Power & Light Company		100

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

OFFICERS
Report below the name, title and salary for each executive officer whose salary is $50,000 or more. An "executive officer" of a respondent includes its president, secretary, treasurer, and vice president in charge of a principal business unit, division or function (such as sales, administration or finance), and any other person who performs similar policy making functions. If a change was made during the year in the incumbent of any position, show name and total remuneration of the previous incumbent, and the date the change in incumbency was made.
Line No.	OfficerTitle Title (a)	OfficerName Name of Officer (b)	OfficerSalary Salary for Year (c)	DateOfficerIncumbencyStarted Date Started in Period (d)	DateOfficerIncumbencyEnded Date Ended in Period (e)
1	President and Chief Executive Officer of Entergy Mississippi	Haley R. Fisackerly	396,604
2	Chief Executive Officer and Chairman of the Board of Entergy Corporation	Leo P. Denault	(a) 0
3	Executive Vice President and Chief Financial Officer	Andrew S. Marsh	(b) 0
4	Executive Vice President and Chief Operating Officer	Paul D. Hinnenkamp	(c) 0
5	Executive Vice President and General Counsel	Marcus V. Brown	(d) 0
6	Group President Utility Operations	Roderick K. West	(e) 0
7	Senior Vice President and Chief Accounting Officer	Kimberly A. Fontan	(f) 0
8	Senior Vice President and General Tax Counsel	Joseph T. Henderson	(g) 0		2021-08-02
9	Vice President and General Tax Counsel	Steven W. Brady	(h) 0	2021-08-02

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: OfficerSalary

Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.

(b) Concept: OfficerSalary

Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.

(c) Concept: OfficerSalary

Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.

(d) Concept: OfficerSalary

Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.

(e) Concept: OfficerSalary

Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.

(f) Concept: OfficerSalary

Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.

(g) Concept: OfficerSalary

Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.

(h) Concept: OfficerSalary

Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

DIRECTORS
Report below the information called for concerning each director of the respondent who held office at any time during the year. Include in column (a), name and abbreviated titles of the directors who are officers of the respondent. Provide the principle place of business in column (b), designate members of the Executive Committee in column (c), and the Chairman of the Executive Committee in column (d).
Line No.	NameAndTitleOfDirector Name (and Title) of Director (a)	PrincipalBusinessAddress Principal Business Address (b)	MemberOfTheExecutiveCommittee Member of the Executive Committee (c)	ChairmanOfTheExecutiveCommittee Chairman of the Executive Committee (d)
1	Haley R. Fisackerly - President and Chief Executive Officer of Entergy Mississippi	308 East Pearl Street, Jackson, MS 39201	false	false
2	Andrew S. Marsh - Executive Vice President and Chief Financial Officer	639 Loyola Avenue, New Orleans, LA 70113	true	false
3	Roderick K. West - Group President Utility Operations	639 Loyola Avenue, New Orleans, LA 70113	true	false
4	Paul D. Hinnenkamp - Executive Vice President and Chief Operating Officer	639 Loyola Avenue, New Orleans, LA 70113	true	false

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

INFORMATION ON FORMULA RATES
Does the respondent have formula rates?		☑ Yes ☐ No
Please list the Commission accepted formula rates including FERC Rate Schedule or Tariff Number and FERC proceeding (i.e. Docket No) accepting the rate(s) or changes in the accepted rate.
Line No.	RateScheduleTariffNumber FERC Rate Schedule or Tariff Number (a)	ProceedingDocketNumber FERC Proceeding (b)
1	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Baseline Tariff	Docket No. ER13-1508
2	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff	Docket No. ER16-2199
3	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff	Docket No. ER18-1247
4	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff	Docket No. ER19-747
5	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff	Docket No. ER21-915
6	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff	Docket No. ER21-1720
7	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff	Docket No. ER21-1997
8	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff	Docket No. ER21-2169
9	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tarriff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff	Docket No. ER22-489
10	Midcontinent Indepedent System Operator (MISO) FERC Electric Tariff - Fifth Revised Volume 1	Docket No. ER13-948
11	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER14-649
12	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER15-358
13	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER15-1436
14	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER16-227
15	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER16-1322
16	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER17-215
17	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER17-1549
18	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER17-1777
19	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER17-2579
20	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER18-1260
21	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER18-1982
22	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER19-652
23	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER19-1503
24	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER17-827
25	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER20-1449
26	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER20-1472
27	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER21-200
28	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER21-262
29	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER21-2693

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

INFORMATION ON FORMULA RATES - FERC Rate Schedule/Tariff Number FERC Proceeding
Does the respondent file with the Commission annual (or more frequent) filings containing the inputs to the formula rate(s)?			☑ Yes ☐ No
If yes, provide a listing of such filings as contained on the Commission's eLibrary website.
Line No.	AccessionNumber Accession No. (a)	DocumentDate Document Date / Filed Date (b)	DocketNumber Docket No. (c)	DescriptionOfFiling Description (d)	RateScheduleTariffNumber Formula Rate FERC Rate Schedule Number or Tariff Number (e)
1	20210315-5351	03/15/2021	ER21-1429	(a) Annual Informational MISO Attachment O Transmission Formula Rate Update

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: DescriptionOfFiling

Pursuant to the Federal Energy Regulatory Commission’s orders in Docket Nos. EL12-35 and ER13-2379 and the Annual Update, Information Exchange, and Challenge Procedures of the Entergy Operating Companies set forth in Attachment O of the Midcontinent Independent System Operator, Inc.’s Open Access Transmission, Energy and Operating Reserve Markets Tariff, Entergy Services shall submit an annual Informational Filing on March 15 based on data for the second preceding calendar year data. The 2019 update was filed on March 15, 2021 in Docket No. ER21-1429. This Informational Filing is not a rate filing. It shows the development of the Entergy Operating Companies’ annual transmission revenue requirements for billing June 1, 2020 through May 31, 2021 through the application of data for Calendar Year 2019 under the Attachment O MISO Tariff.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

INFORMATION ON FORMULA RATES - Formula Rate Variances
If a respondent does not submit such filings then indicate in a footnote to the applicable Form 1 schedule where formula rate inputs differ from amounts reported in the Form 1. The footnote should provide a narrative description explaining how the "rate" (or billing) was derived if different from the reported amount in the Form 1. The footnote should explain amounts excluded from the ratebase or where labor or other allocation factors, operating expenses, or other items impacting formula rate inputs differ from amounts reported in Form 1 schedule amounts. Where the Commission has provided guidance on formula rate inputs, the specific proceeding should be noted in the footnote.
Line No.	PageNumberOfFormulaRateVariances Page No(s). (a)	ScheduleOfFormulaRateVariances Schedule (b)	ColumnOfFormulaRateVariances Column (c)	LineNumberOfFormulaRateVariances Line No. (d)
1		NONE

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

IMPORTANT CHANGES DURING THE QUARTER/YEAR
Give particulars (details) concerning the matters indicated below. Make the statements explicit and precise, and number them in accordance with the inquiries. Each inquiry should be answered. Enter "none," "not applicable," or "NA" where applicable. If information which answers an inquiry is given elsewhere in the report, make a reference to the schedule in which it appears. Changes in and important additions to franchise rights: Describe the actual consideration given therefore and state from whom the franchise rights were acquired. If acquired without the payment of consideration, state that fact. Acquisition of ownership in other companies by reorganization, merger, or consolidation with other companies: Give names of companies involved, particulars concerning the transactions, name of the Commission authorizing the transaction, and reference to Commission authorization. Purchase or sale of an operating unit or system: Give a brief description of the property, and of the transactions relating thereto, and reference to Commission authorization, if any was required. Give date journal entries called for by the Uniform System of Accounts were submitted to the Commission. Important leaseholds (other than leaseholds for natural gas lands) that have been acquired or given, assigned or surrendered: Give effective dates, lengths of terms, names of parties, rents, and other condition. State name of Commission authorizing lease and give reference to such authorization. Important extension or reduction of transmission or distribution system: State territory added or relinquished and date operations began or ceased and give reference to Commission authorization, if any was required. State also the approximate number of customers added or lost and approximate annual revenues of each class of service. Each natural gas company must also state major new continuing sources of gas made available to it from purchases, development, purchase contract or otherwise, giving location and approximate total gas volumes available, period of contracts, and other parties to any such arrangements, etc. Obligations incurred as a result of issuance of securities or assumption of liabilities or guarantees including issuance of short-term debt and commercial paper having a maturity of one year or less. Give reference to FERC or State Commission authorization, as appropriate, and the amount of obligation or guarantee. Changes in articles of incorporation or amendments to charter: Explain the nature and purpose of such changes or amendments. State the estimated annual effect and nature of any important wage scale changes during the year. State briefly the status of any materially important legal proceedings pending at the end of the year, and the results of any such proceedings culminated during the year. Describe briefly any materially important transactions of the respondent not disclosed elsewhere in this report in which an officer, director, security holder reported on Pages 104 or 105 of the Annual Report Form No. 1, voting trustee, associated company or known associate of any of these persons was a party or in which any such person had a material interest. (Reserved.) If the important changes during the year relating to the respondent company appearing in the annual report to stockholders are applicable in every respect and furnish the data required by Instructions 1 to 11 above, such notes may be included on this page. Describe fully any changes in officers, directors, major security holders and voting powers of the respondent that may have occurred during the reporting period. In the event that the respondent participates in a cash management program(s) and its proprietary capital ratio is less than 30 percent please describe the significant events or transactions causing the proprietary capital ratio to be less than 30 percent, and the extent to which the respondent has amounts loaned or money advanced to its parent, subsidiary, or affiliated companies through a cash management program(s). Additionally, please describe plans, if any to regain at least a 30 percent proprietary ratio.

1.None
2. None
3. None
4. None
5. None
6. See Entergy Mississippi's 2021 FERC Form 1 Notes to Financial Statements, Notes 4, 5, and 8.
7. None
8. Transmission, distribution, and utility support employees are represented by the International Brotherhood of Electrical Workers AFL-CIO, Local Unions 605 and 985. The Company and the Union agreed to a contract effective October 16, 2019 through October 15, 2022. Effective October 15, 2021, the wage increase was 2.0%. Fossil operating employees are represented by the International Brotherhood of Electrical Workers AFL-CIO, Local Unions 605 and 985. The Company and the Union agreed to a contract effective April 15, 2019 through April 15, 2022. Effective April 15, 2021, the wage increase was 2.0%. Effective April 1, 2021, executive and senior management, middle management, professionals, and non-represented operating, maintenance, and support staff pay increases averaged approximately 3.0%.
9. See Entergy Mississippi’s 2021 FERC Form 1 Notes to Financial Statements, Notes 2 and 8.
10. None
12. See Entergy Mississippi's 2021 FERC Form 1 Notes to Financial Statements.
13. See Entergy Mississippi’s 2021 FERC Form 1 pages 104 and 105 for Officer and Director changes that occurred in 2021.
14. Not applicable

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITS)
Line No.	Title of Account (a)	Ref. Page No. (b)	Current Year End of Quarter/Year Balance (c)	Prior Year End Balance 12/31 (d)
1	UtilityPlantAbstract UTILITY PLANT
2	UtilityPlant Utility Plant (101-106, 114)	200	6,616,604,360	6,086,747,735
3	ConstructionWorkInProgress Construction Work in Progress (107)	200	95,935,092	135,177,686
4	UtilityPlantAndConstructionWorkInProgress TOTAL Utility Plant (Enter Total of lines 2 and 3)		6,712,539,452	6,221,925,421
5	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility (Less) Accum. Prov. for Depr. Amort. Depl. (108, 110, 111, 115)	200	(a) 1,991,077,854	(b) 1,897,869,011
6	UtilityPlantNet Net Utility Plant (Enter Total of line 4 less 5)		4,721,461,598	4,324,056,410
7	NuclearFuelInProcessOfRefinementConversionEnrichmentAndFabrication Nuclear Fuel in Process of Ref., Conv., Enrich., and Fab. (120.1)	202
8	NuclearFuelMaterialsAndAssembliesStockAccountMajorOnly Nuclear Fuel Materials and Assemblies-Stock Account (120.2)
9	NuclearFuelAssembliesInReactorMajorOnly Nuclear Fuel Assemblies in Reactor (120.3)
10	SpentNuclearFuelMajorOnly Spent Nuclear Fuel (120.4)
11	NuclearFuelUnderCapitalLeases Nuclear Fuel Under Capital Leases (120.6)
12	AccumulatedProvisionForAmortizationOfNuclearFuelAssemblies (Less) Accum. Prov. for Amort. of Nucl. Fuel Assemblies (120.5)	202
13	NuclearFuelNet Net Nuclear Fuel (Enter Total of lines 7-11 less 12)
14	UtilityPlantAndNuclearFuelNet Net Utility Plant (Enter Total of lines 6 and 13)		4,721,461,598	4,324,056,410
15	OtherElectricPlantAdjustments Utility Plant Adjustments (116)
16	GasStoredUndergroundNoncurrent Gas Stored Underground - Noncurrent (117)
17	OtherPropertyAndInvestmentsAbstract OTHER PROPERTY AND INVESTMENTS
18	NonutilityProperty Nonutility Property (121)		5,076,754	5,076,754
19	AccumulatedProvisionForDepreciationAndAmortizationOfNonutilityProperty (Less) Accum. Prov. for Depr. and Amort. (122)		549,813	533,518
20	InvestmentInAssociatedCompanies Investments in Associated Companies (123)
21	InvestmentInSubsidiaryCompanies Investment in Subsidiary Companies (123.1)	224	2,242	10,547
23	NoncurrentPortionOfAllowances Noncurrent Portion of Allowances	228
24	OtherInvestments Other Investments (124)
25	SinkingFunds Sinking Funds (125)
26	DepreciationFund Depreciation Fund (126)
27	AmortizationFundFederal Amortization Fund - Federal (127)
28	OtherSpecialFunds Other Special Funds (128)		48,885,707	64,634,756
29	SpecialFunds Special Funds (Non Major Only) (129)
30	DerivativeInstrumentAssetsLongTerm Long-Term Portion of Derivative Assets (175)
31	DerivativeInstrumentAssetsHedgesLongTerm Long-Term Portion of Derivative Assets - Hedges (176)
32	OtherPropertyAndInvestments TOTAL Other Property and Investments (Lines 18-21 and 23-31)		53,414,890	69,188,539
33	CurrentAndAccruedAssetsAbstract CURRENT AND ACCRUED ASSETS
34	CashAndWorkingFunds Cash and Working Funds (Non-major Only) (130)
35	Cash Cash (131)		28,264	10,613
36	SpecialDeposits Special Deposits (132-134)			1,381,940
37	WorkingFunds Working Fund (135)
38	TemporaryCashInvestments Temporary Cash Investments (136)		47,595,970
39	NotesReceivable Notes Receivable (141)
40	CustomerAccountsReceivable Customer Accounts Receivable (142)		84,047,722	105,732,155
41	OtherAccountsReceivable Other Accounts Receivable (143)		14,608,590	11,820,518
42	AccumulatedProvisionForUncollectibleAccountsCredit (Less) Accum. Prov. for Uncollectible Acct.-Credit (144)		7,209,104	19,526,736
43	NotesReceivableFromAssociatedCompanies Notes Receivable from Associated Companies (145)
44	AccountsReceivableFromAssociatedCompanies Accounts Receivable from Assoc. Companies (146)		42,993,614	2,740,230
45	FuelStock Fuel Stock (151)	227	10,290,914	17,004,333
46	FuelStockExpensesUndistributed Fuel Stock Expenses Undistributed (152)	227		66,020
47	Residuals Residuals (Elec) and Extracted Products (153)	227
48	PlantMaterialsAndOperatingSupplies Plant Materials and Operating Supplies (154)	227	66,127,931	55,560,534
49	Merchandise Merchandise (155)	227
50	OtherMaterialsAndSupplies Other Materials and Supplies (156)	227
51	NuclearMaterialsHeldForSale Nuclear Materials Held for Sale (157)	202/227
52	AllowanceInventoryAndWithheld Allowances (158.1 and 158.2)	228	20,170	46,554
53	NoncurrentPortionOfAllowances (Less) Noncurrent Portion of Allowances	228
54	StoresExpenseUndistributed Stores Expense Undistributed (163)	227	3,510,746	3,981,225
55	GasStoredCurrent Gas Stored Underground - Current (164.1)
56	LiquefiedNaturalGasStoredAndHeldForProcessing Liquefied Natural Gas Stored and Held for Processing (164.2-164.3)
57	Prepayments Prepayments (165)		16,445,586	14,052,081
58	AdvancesForGas Advances for Gas (166-167)
59	InterestAndDividendsReceivable Interest and Dividends Receivable (171)		1,317	131
60	RentsReceivable Rents Receivable (172)
61	AccruedUtilityRevenues Accrued Utility Revenues (173)		56,033,772	59,514,433
62	MiscellaneousCurrentAndAccruedAssets Miscellaneous Current and Accrued Assets (174)		17,470	309,902
63	DerivativeInstrumentAssets Derivative Instrument Assets (175)		294,549	638,258
64	DerivativeInstrumentAssetsLongTerm (Less) Long-Term Portion of Derivative Instrument Assets (175)
65	DerivativeInstrumentAssetsHedges Derivative Instrument Assets - Hedges (176)
66	DerivativeInstrumentAssetsHedgesLongTerm (Less) Long-Term Portion of Derivative Instrument Assets - Hedges (176)
67	CurrentAndAccruedAssets Total Current and Accrued Assets (Lines 34 through 66)		334,807,511	253,332,191
68	DeferredDebitsAbstract DEFERRED DEBITS
69	UnamortizedDebtExpense Unamortized Debt Expenses (181)		20,864,002	18,107,904
70	ExtraordinaryPropertyLosses Extraordinary Property Losses (182.1)	230a
71	UnrecoveredPlantAndRegulatoryStudyCosts Unrecovered Plant and Regulatory Study Costs (182.2)	230b
72	OtherRegulatoryAssets Other Regulatory Assets (182.3)	232	457,274,699	344,331,627
73	PreliminarySurveyAndInvestigationCharges Prelim. Survey and Investigation Charges (Electric) (183)		891,053	74,533
74	PreliminaryNaturalGasSurveyAndInvestigationChargesAndOtherPreliminarySurveyAndInvestigationCharges Preliminary Natural Gas Survey and Investigation Charges 183.1)
75	OtherPreliminarySurveyAndInvestigationCharges Other Preliminary Survey and Investigation Charges (183.2)
76	ClearingAccounts Clearing Accounts (184)		182,547	380,956
77	TemporaryFacilities Temporary Facilities (185)
78	MiscellaneousDeferredDebits Miscellaneous Deferred Debits (186)	233	2,315,100	2,381,750
79	DeferredLossesFromDispositionOfUtilityPlant Def. Losses from Disposition of Utility Plt. (187)
80	ResearchDevelopmentAndDemonstrationExpenditures Research, Devel. and Demonstration Expend. (188)	352
81	UnamortizedLossOnReacquiredDebt Unamortized Loss on Reaquired Debt (189)		12,159,775	13,516,748
82	AccumulatedDeferredIncomeTaxes Accumulated Deferred Income Taxes (190)	234	607,243,412	604,138,349
83	UnrecoveredPurchasedGasCosts Unrecovered Purchased Gas Costs (191)
84	DeferredDebits Total Deferred Debits (lines 69 through 83)		1,100,930,588	982,931,867
85	AssetsAndOtherDebits TOTAL ASSETS (lines 14-16, 32, 67, and 84)		6,210,614,587	5,629,509,007

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility

Includes a debit balance for removal costs of $136,760,640.

(b) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility

Includes a debit balance for removal costs of $107,265,805.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDITS)
Line No.	Title of Account (a)	Ref. Page No. (b)	Current Year End of Quarter/Year Balance (c)	Prior Year End Balance 12/31 (d)
1	ProprietaryCapitalAbstract PROPRIETARY CAPITAL
2	CommonStockIssued Common Stock Issued (201)	250
3	PreferredStockIssued Preferred Stock Issued (204)	250
4	CapitalStockSubscribed Capital Stock Subscribed (202, 205)
5	StockLiabilityForConversion Stock Liability for Conversion (203, 206)
6	PremiumOnCapitalStock Premium on Capital Stock (207)
7	OtherPaidInCapital Other Paid-In Capital (208-211)	253	329,266,361	329,266,361
8	InstallmentsReceivedOnCapitalStock Installments Received on Capital Stock (212)	252
9	DiscountOnCapitalStock (Less) Discount on Capital Stock (213)	254
10	CapitalStockExpense (Less) Capital Stock Expense (214)	254b
11	RetainedEarnings Retained Earnings (215, 215.1, 216)	118	1,510,306,089	1,343,471,946
12	UnappropriatedUndistributedSubsidiaryEarnings Unappropriated Undistributed Subsidiary Earnings (216.1)	118	3,970	3,970
13	ReacquiredCapitalStock (Less) Reaquired Capital Stock (217)	250
14	NoncorporateProprietorship Noncorporate Proprietorship (Non-major only) (218)
15	AccumulatedOtherComprehensiveIncome Accumulated Other Comprehensive Income (219)	122(a)(b)
16	ProprietaryCapital Total Proprietary Capital (lines 2 through 15)		1,839,568,480	1,672,734,337
17	LongTermDebtAbstract LONG-TERM DEBT
18	Bonds Bonds (221)	256	2,195,000,000	1,795,000,000
19	ReacquiredBonds (Less) Reaquired Bonds (222)	256
20	AdvancesFromAssociatedCompanies Advances from Associated Companies (223)	256
21	OtherLongTermDebt Other Long-Term Debt (224)	256
22	UnamortizedPremiumOnLongTermDebt Unamortized Premium on Long-Term Debt (225)		12,719,332	10,404,637
23	UnamortizedDiscountOnLongTermDebtDebit (Less) Unamortized Discount on Long-Term Debt-Debit (226)		6,865,924	6,719,830
24	LongTermDebt Total Long-Term Debt (lines 18 through 23)		2,200,853,408	1,798,684,807
25	OtherNoncurrentLiabilitiesAbstract OTHER NONCURRENT LIABILITIES
26	ObligationsUnderCapitalLeaseNoncurrent Obligations Under Capital Leases - Noncurrent (227)		18,247,593	16,674,384
27	AccumulatedProvisionForPropertyInsurance Accumulated Provision for Property Insurance (228.1)		33,185,707	40,850,588
28	AccumulatedProvisionForInjuriesAndDamages Accumulated Provision for Injuries and Damages (228.2)		4,426,225	5,236,954
29	AccumulatedProvisionForPensionsAndBenefits Accumulated Provision for Pensions and Benefits (228.3)		33,927,919	28,311,733
30	AccumulatedMiscellaneousOperatingProvisions Accumulated Miscellaneous Operating Provisions (228.4)		416,001	416,001
31	AccumulatedProvisionForRateRefunds Accumulated Provision for Rate Refunds (229)
32	LongTermPortionOfDerivativeInstrumentLiabilities Long-Term Portion of Derivative Instrument Liabilities
33	LongTermPortionOfDerivativeInstrumentLiabilitiesHedges Long-Term Portion of Derivative Instrument Liabilities - Hedges
34	AssetRetirementObligations Asset Retirement Obligations (230)		10,314,948	9,762,395
35	OtherNoncurrentLiabilities Total Other Noncurrent Liabilities (lines 26 through 34)		32,662,555	44,628,589
36	CurrentAndAccruedLiabilitiesAbstract CURRENT AND ACCRUED LIABILITIES
37	NotesPayable Notes Payable (231)
38	AccountsPayable Accounts Payable (232)		112,999,501	117,628,516
39	NotesPayableToAssociatedCompanies Notes Payable to Associated Companies (233)
40	AccountsPayableToAssociatedCompanies Accounts Payable to Associated Companies (234)		42,928,967	61,726,899
41	CustomerDeposits Customer Deposits (235)		86,166,586	86,200,023
42	TaxesAccrued Taxes Accrued (236)	262	158,851,699	157,423,016
43	InterestAccrued Interest Accrued (237)		19,683,085	22,789,449
44	DividendsDeclared Dividends Declared (238)
45	MaturedLongTermDebt Matured Long-Term Debt (239)
46	MaturedInterest Matured Interest (240)
47	TaxCollectionsPayable Tax Collections Payable (241)		2,299,129	1,869,025
48	MiscellaneousCurrentAndAccruedLiabilities Miscellaneous Current and Accrued Liabilities (242)		17,055,527	16,824,713
49	ObligationsUnderCapitalLeasesCurrent Obligations Under Capital Leases-Current (243)		7,709,028	7,381,893
50	DerivativesInstrumentLiabilities Derivative Instrument Liabilities (244)		6,709,364	5,020,445
51	LongTermPortionOfDerivativeInstrumentLiabilities (Less) Long-Term Portion of Derivative Instrument Liabilities
52	DerivativeInstrumentLiabilitiesHedges Derivative Instrument Liabilities - Hedges (245)
53	LongTermPortionOfDerivativeInstrumentLiabilitiesHedges (Less) Long-Term Portion of Derivative Instrument Liabilities-Hedges
54	CurrentAndAccruedLiabilities Total Current and Accrued Liabilities (lines 37 through 53)		454,402,886	476,863,979
55	DeferredCreditsAbstract DEFERRED CREDITS
56	CustomerAdvancesForConstruction Customer Advances for Construction (252)		16,460,070	13,249,413
57	AccumulatedDeferredInvestmentTaxCredits Accumulated Deferred Investment Tax Credits (255)	266	10,912,780	9,062,299
58	DeferredGainsFromDispositionOfUtilityPlant Deferred Gains from Disposition of Utility Plant (256)
59	OtherDeferredCredits Other Deferred Credits (253)	269	96,517,003	160,192,783
60	OtherRegulatoryLiabilities Other Regulatory Liabilities (254)	278	286,875,679	254,519,520
61	UnamortizedGainOnReacquiredDebt Unamortized Gain on Reaquired Debt (257)
62	AccumulatedDeferredIncomeTaxesAcceleratedAmortizationProperty Accum. Deferred Income Taxes-Accel. Amort.(281)	272
63	AccumulatedDeferredIncomeTaxesOtherProperty Accum. Deferred Income Taxes-Other Property (282)		709,519,498	661,156,573
64	AccumulatedDeferredIncomeTaxesOther Accum. Deferred Income Taxes-Other (283)		562,842,228	538,416,707
65	DeferredCredits Total Deferred Credits (lines 56 through 64)		1,683,127,258	1,636,597,295
66	LiabilitiesAndOtherCredits TOTAL LIABILITIES AND STOCKHOLDER EQUITY (lines 16, 24, 35, 54 and 65)		6,210,614,587	5,629,509,007

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

STATEMENT OF INCOME
Quarterly Report in column (c) the current year to date balance. Column (c) equals the total of adding the data in column (g) plus the data in column (i) plus the data in column (k). Report in column (d) similar data for the previous year. This information is reported in the annual filing only. Enter in column (e) the balance for the reporting quarter and in column (f) the balance for the same three month period for the prior year. Report in column (g) the quarter to date amounts for electric utility function; in column (i) the quarter to date amounts for gas utility, and in column (k) the quarter to date amounts for other utility function for the current year quarter. Report in column (h) the quarter to date amounts for electric utility function; in column (j) the quarter to date amounts for gas utility, and in column (l) the quarter to date amounts for other utility function for the prior year quarter. If additional columns are needed, place them in a footnote. Annual or Quarterly if applicable Do not report fourth quarter data in columns (e) and (f) Report amounts for accounts 412 and 413, Revenues and Expenses from Utility Plant Leased to Others, in another utility column in a similar manner to a utility department. Spread the amount(s) over Lines 2 thru 26 as appropriate. Include these amounts in columns (c) and (d) totals. Report amounts in account 414, Other Utility Operating Income, in the same manner as accounts 412 and 413 above. Use page 122 for important notes regarding the statement of income for any account thereof. Give concise explanations concerning unsettled rate proceedings where a contingency exists such that refunds of a material amount may need to be made to the utility's customers or which may result in material refund to the utility with respect to power or gas purchases. State for each year effected the gross revenues or costs to which the contingency relates and the tax effects together with an explanation of the major factors which affect the rights of the utility to retain such revenues or recover amounts paid with respect to power or gas purchases. Give concise explanations concerning significant amounts of any refunds made or received during the year resulting from settlement of any rate proceeding affecting revenues received or costs incurred for power or gas purchases, and a summary of the adjustments made to balance sheet, income, and expense accounts. If any notes appearing in the report to stockholders are applicable to the Statement of Income, such notes may be included at page 122. Enter on page 122 a concise explanation of only those changes in accounting methods made during the year which had an effect on net income, including the basis of allocations and apportionments from those used in the preceding year. Also, give the appropriate dollar effect of such changes. Explain in a footnote if the previous year's/quarter's figures are different from that reported in prior reports. If the columns are insufficient for reporting additional utility departments, supply the appropriate account titles report the information in a footnote to this schedule.
Line No.	Title of Account (a)	(Ref.) Page No. (b)	Total Current Year to Date Balance for Quarter/Year (c)	Total Prior Year to Date Balance for Quarter/Year (d)	Current 3 Months Ended - Quarterly Only - No 4th Quarter (e)	Prior 3 Months Ended - Quarterly Only - No 4th Quarter (f)	Electric Utility Current Year to Date (in dollars) (g)	Electric Utility Previous Year to Date (in dollars) (h)	Gas Utiity Current Year to Date (in dollars) (i)	Gas Utility Previous Year to Date (in dollars) (j)	Other Utility Current Year to Date (in dollars) (k)	Other Utility Previous Year to Date (in dollars) (l)
1	UtilityOperatingIncomeAbstract UTILITY OPERATING INCOME
2	OperatingRevenues Operating Revenues (400)	300	1,406,346,287	1,247,854,547			1,406,346,287	1,247,854,547
3	OperatingExpensesAbstract Operating Expenses
4	OperationExpense Operation Expenses (401)	320	697,588,741	639,715,857			697,588,741	639,715,857
5	MaintenanceExpense Maintenance Expenses (402)	320	84,691,764	81,441,325			84,691,764	81,441,325
6	DepreciationExpense Depreciation Expense (403)	336	202,917,586	188,961,954			202,917,586	188,961,954
7	DepreciationExpenseForAssetRetirementCosts Depreciation Expense for Asset Retirement Costs (403.1)	336	11,486	10,153			11,486	10,153
8	AmortizationAndDepletionOfUtilityPlant Amort. & Depl. of Utility Plant (404-405)	336	20,508,961	17,000,545			20,508,961	17,000,545
9	AmortizationOfElectricPlantAcquisitionAdjustments Amort. of Utility Plant Acq. Adj. (406)	336	2,722,019	2,764,420			2,722,019	2,764,420
10	AmortizationOfPropertyLossesUnrecoveredPlantAndRegulatoryStudyCosts Amort. Property Losses, Unrecov Plant and Regulatory Study Costs (407)
11	AmortizationOfConversionExpenses Amort. of Conversion Expenses (407.2)
12	RegulatoryDebits Regulatory Debits (407.3)		57,132,213	10,034,479			57,132,213	10,034,479
13	RegulatoryCredits (Less) Regulatory Credits (407.4)		51,219,492	25,253,475			51,219,492	25,253,475
14	TaxesOtherThanIncomeTaxesUtilityOperatingIncome Taxes Other Than Income Taxes (408.1)	262	111,711,558	101,524,934			111,711,558	101,524,934
15	IncomeTaxesOperatingIncome Income Taxes - Federal (409.1)	262	3,023,595	26,215,013			3,023,595	26,215,013
16	IncomeTaxesUtilityOperatingIncomeOther Income Taxes - Other (409.1)	262	10,812,857	8,575,529			10,812,857	8,575,529
17	ProvisionsForDeferredIncomeTaxesUtilityOperatingIncome Provision for Deferred Income Taxes (410.1)	234, 272	316,143,266	243,696,378			316,143,266	243,696,378
18	ProvisionForDeferredIncomeTaxesCreditOperatingIncome (Less) Provision for Deferred Income Taxes-Cr. (411.1)	234, 272	257,370,008	248,926,859			257,370,008	248,926,859
19	InvestmentTaxCreditAdjustments Investment Tax Credit Adj. - Net (411.4)	266	1,836,307	554,085			1,836,307	554,085
20	GainsFromDispositionOfPlant (Less) Gains from Disp. of Utility Plant (411.6)
21	LossesFromDispositionOfServiceCompanyPlant Losses from Disp. of Utility Plant (411.7)
22	GainsFromDispositionOfAllowances (Less) Gains from Disposition of Allowances (411.8)
23	LossesFromDispositionOfAllowances Losses from Disposition of Allowances (411.9)
24	AccretionExpense Accretion Expense (411.10)		552,553	536,902			552,553	536,902
25	UtilityOperatingExpenses TOTAL Utility Operating Expenses (Enter Total of lines 4 thru 24)		1,173,390,502	1,045,743,070			1,173,390,502	1,045,743,070
27	NetUtilityOperatingIncome Net Util Oper Inc (Enter Tot line 2 less 25)		232,955,785	202,111,477			232,955,785	202,111,477
28	OtherIncomeAndDeductionsAbstract Other Income and Deductions
29	OtherIncomeAbstract Other Income
30	NonutilityOperatingIncomeAbstract Nonutilty Operating Income
31	RevenuesFromMerchandisingJobbingAndContractWork Revenues From Merchandising, Jobbing and Contract Work (415)
32	CostsAndExpensesOfMerchandisingJobbingAndContractWork (Less) Costs and Exp. of Merchandising, Job. & Contract Work (416)
33	RevenuesFromNonutilityOperations Revenues From Nonutility Operations (417)
34	ExpensesOfNonutilityOperations (Less) Expenses of Nonutility Operations (417.1)		16,296	16,296
35	NonoperatingRentalIncome Nonoperating Rental Income (418)
36	EquityInEarningsOfSubsidiaryCompanies Equity in Earnings of Subsidiary Companies (418.1)	119		405
37	InterestAndDividendIncome Interest and Dividend Income (419)		53,379	271,577
38	AllowanceForOtherFundsUsedDuringConstruction Allowance for Other Funds Used During Construction (419.1)		8,101,351	6,725,874
39	MiscellaneousNonoperatingIncome Miscellaneous Nonoperating Income (421)		1,126,249	110,661
40	GainOnDispositionOfProperty Gain on Disposition of Property (421.1)		95,187	4,158
41	OtherIncome TOTAL Other Income (Enter Total of lines 31 thru 40)		9,359,870	7,095,569
42	OtherIncomeDeductionsAbstract Other Income Deductions
43	LossOnDispositionOfProperty Loss on Disposition of Property (421.2)		43,618
44	MiscellaneousAmortization Miscellaneous Amortization (425)
45	Donations Donations (426.1)		1,651,277	828,456
46	LifeInsurance Life Insurance (426.2)
47	Penalties Penalties (426.3)		8,618	104,839
48	ExpendituresForCertainCivicPoliticalAndRelatedActivities Exp. for Certain Civic, Political & Related Activities (426.4)		2,596,819	2,258,385
49	OtherDeductions Other Deductions (426.5)		940,946	1,082,385
50	OtherIncomeDeductions TOTAL Other Income Deductions (Total of lines 43 thru 49)		5,224,042	4,274,065
51	TaxesApplicableToOtherIncomeAndDeductionsAbstract Taxes Applic. to Other Income and Deductions
52	TaxesOtherThanIncomeTaxesOtherIncomeAndDeductions Taxes Other Than Income Taxes (408.2)	262
53	IncomeTaxesFederal Income Taxes-Federal (409.2)	262	1,559,370	1,612,355
54	IncomeTaxesOther Income Taxes-Other (409.2)	262	390,820	404,099
55	ProvisionForDeferredIncomeTaxesOtherIncomeAndDeductions Provision for Deferred Inc. Taxes (410.2)	234, 272
56	ProvisionForDeferredIncomeTaxesCreditOtherIncomeAndDeductions (Less) Provision for Deferred Income Taxes-Cr. (411.2)	234, 272
57	InvestmentTaxCreditAdjustmentsNonutilityOperations Investment Tax Credit Adj.-Net (411.5)
58	InvestmentTaxCredits (Less) Investment Tax Credits (420)
59	TaxesOnOtherIncomeAndDeductions TOTAL Taxes on Other Income and Deductions (Total of lines 52-58)		1,950,190	2,016,454
60	NetOtherIncomeAndDeductions Net Other Income and Deductions (Total of lines 41, 50, 59)		6,086,018	4,837,958
61	InterestChargesAbstract Interest Charges
62	InterestOnLongTermDebt Interest on Long-Term Debt (427)		71,242,944	62,655,583
63	AmortizationOfDebtDiscountAndExpense Amort. of Debt Disc. and Expense (428)		1,567,681	1,428,230
64	AmortizationOfLossOnReacquiredDebt Amortization of Loss on Reaquired Debt (428.1)		1,356,973	1,356,973
65	AmortizationOfPremiumOnDebtCredit (Less) Amort. of Premium on Debt-Credit (429)		439,305	366,146
66	AmortizationOfGainOnReacquiredDebtCredit (Less) Amortization of Gain on Reaquired Debt-Credit (429.1)
67	InterestOnDebtToAssociatedCompanies Interest on Debt to Assoc. Companies (430)		6,515	35,280
68	OtherInterestExpense Other Interest Expense (431)		1,888,738	4,034,750
69	AllowanceForBorrowedFundsUsedDuringConstructionCredit (Less) Allowance for Borrowed Funds Used During Construction-Cr. (432)		3,415,886	2,778,310
70	NetInterestCharges Net Interest Charges (Total of lines 62 thru 69)		72,207,660	66,366,360
71	IncomeBeforeExtraordinaryItems Income Before Extraordinary Items (Total of lines 27, 60 and 70)		166,834,143	140,583,075
72	ExtraordinaryItemsAbstract Extraordinary Items
73	ExtraordinaryIncome Extraordinary Income (434)
74	ExtraordinaryDeductions (Less) Extraordinary Deductions (435)
75	NetExtraordinaryItems Net Extraordinary Items (Total of line 73 less line 74)
76	IncomeTaxesExtraordinaryItems Income Taxes-Federal and Other (409.3)	262	0
77	ExtraordinaryItemsAfterTaxes Extraordinary Items After Taxes (line 75 less line 76)
78	NetIncomeLoss Net Income (Total of line 71 and 77)		166,834,143	140,583,075

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

STATEMENT OF RETAINED EARNINGS
Do not report Lines 49-53 on the quarterly report. Report all changes in appropriated retained earnings, unappropriated retained earnings, and unappropriated undistributed subsidiary earnings for the year. Each credit and debit during the year should be identified as to the retained earnings account in which recorded (Accounts 433, 436-439 inclusive). Show the contra primary account affected in column (b). State the purpose and amount for each reservation or appropriation of retained earnings. List first Account 439, Adjustments to Retained Earnings, reflecting adjustments to the opening balance of retained earnings. Follow by credit, then debit items, in that order. Show dividends for each class and series of capital stock. Show separately the State and Federal income tax effect of items shown for Account 439, Adjustments to Retained Earnings. Explain in a footnote the basis for determining the amount reserved or appropriated. If such reservation or appropriation is to be recurrent, state the number and annual amounts to be reserved or appropriated as well as the totals eventually to be accumulated. If any notes appearing in the report to stockholders are applicable to this statement, attach them at page 122.
Line No.	Item (a)	Contra Primary Account Affected (b)	Current Quarter/Year Year to Date Balance (c)	Previous Quarter/Year Year to Date Balance (d)
	UnappropriatedRetainedEarningsAbstract UNAPPROPRIATED RETAINED EARNINGS (Account 216)
1	UnappropriatedRetainedEarnings Balance-Beginning of Period		1,343,471,946	1,212,888,466
2	ChangesAbstract Changes
3	AdjustmentsToRetainedEarningsAbstract Adjustments to Retained Earnings (Account 439)
4	AdjustmentsToRetainedEarningsCreditAbstract Adjustments to Retained Earnings Credit
9	AdjustmentsToRetainedEarningsCredit TOTAL Credits to Retained Earnings (Acct. 439)
10	AdjustmentsToRetainedEarningsDebitAbstract Adjustments to Retained Earnings Debit
15	AdjustmentsToRetainedEarningsDebit TOTAL Debits to Retained Earnings (Acct. 439)
16	BalanceTransferredFromIncome Balance Transferred from Income (Account 433 less Account 418.1)		166,834,143	140,583,480
17	AppropriationsOfRetainedEarningsAbstract Appropriations of Retained Earnings (Acct. 436)
22	AppropriationsOfRetainedEarnings TOTAL Appropriations of Retained Earnings (Acct. 436)
23	DividendsDeclaredPreferredStockAbstract Dividends Declared-Preferred Stock (Account 437)
29	DividendsDeclaredPreferredStock TOTAL Dividends Declared-Preferred Stock (Acct. 437)
30	DividendsDeclaredCommonStockAbstract Dividends Declared-Common Stock (Account 438)
30.1	DividendsDeclaredCommonStock Common equity distributions	131		10,000,000
36	DividendsDeclaredCommonStock TOTAL Dividends Declared-Common Stock (Acct. 438)			10,000,000
37	TransfersFromUnappropriatedUndistributedSubsidiaryEarnings Transfers from Acct 216.1, Unapprop. Undistrib. Subsidiary Earnings
38	UnappropriatedRetainedEarnings Balance - End of Period (Total 1,9,15,16,22,29,36,37)		1,510,306,089	1,343,471,946
39	AppropriatedRetainedEarningsAbstract APPROPRIATED RETAINED EARNINGS (Account 215)
45	AppropriatedRetainedEarnings TOTAL Appropriated Retained Earnings (Account 215)
	AppropriatedRetainedEarningsAmortizationReserveFederalAbstract APPROP. RETAINED EARNINGS - AMORT. Reserve, Federal (Account 215.1)
46	AppropriatedRetainedEarningsAmortizationReserveFederal TOTAL Approp. Retained Earnings-Amort. Reserve, Federal (Acct. 215.1)
47	AppropriatedRetainedEarningsIncludingReserveAmortization TOTAL Approp. Retained Earnings (Acct. 215, 215.1) (Total 45,46)
48	RetainedEarnings TOTAL Retained Earnings (Acct. 215, 215.1, 216) (Total 38, 47) (216.1)		1,510,306,089	1,343,471,946
	UnappropriatedUndistributedSubsidiaryEarningsAbstract UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (Account Report only on an Annual Basis, no Quarterly)
49	UnappropriatedUndistributedSubsidiaryEarnings Balance-Beginning of Year (Debit or Credit)		3,970	3,565
50	EquityInEarningsOfSubsidiaryCompanies Equity in Earnings for Year (Credit) (Account 418.1)			405
51	DividendsReceived (Less) Dividends Received (Debit)
52	ChangesUnappropriatedUndistributedSubsidiaryEarningsCredits TOTAL other Changes in unappropriated undistributed subsidiary earnings for the year
53	UnappropriatedUndistributedSubsidiaryEarnings Balance-End of Year (Total lines 49 thru 52)		3,970	3,970

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

STATEMENT OF CASH FLOWS
Codes to be used:(a) Net Proceeds or Payments;(b)Bonds, debentures and other long-term debt; (c) Include commercial paper; and (d) Identify separately such items as investments, fixed assets, intangibles, etc. Information about noncash investing and financing activities must be provided in the Notes to the Financial statements. Also provide a reconciliation between "Cash and Cash Equivalents at End of Period" with related amounts on the Balance Sheet. Operating Activities - Other: Include gains and losses pertaining to operating activities only. Gains and losses pertaining to investing and financing activities should be reported in those activities. Show in the Notes to the Financials the amounts of interest paid (net of amount capitalized) and income taxes paid. Investing Activities: Include at Other (line 31) net cash outflow to acquire other companies. Provide a reconciliation of assets acquired with liabilities assumed in the Notes to the Financial Statements. Do not include on this statement the dollar amount of leases capitalized per the USofA General Instruction 20; instead provide a reconciliation of the dollar amount of leases capitalized with the plant cost.
Line No.	Description (See Instructions No.1 for explanation of codes) (a)	Current Year to Date Quarter/Year (b)	Previous Year to Date Quarter/Year (c)
1	NetCashFlowFromOperatingActivitiesAbstract Net Cash Flow from Operating Activities
2	NetIncomeLoss Net Income (Line 78(c) on page 117)	166,834,143	140,583,075
3	NoncashChargesCreditsToIncomeAbstract Noncash Charges (Credits) to Income:
4	DepreciationAndDepletion Depreciation and Depletion	226,712,605	209,273,974
5	NoncashAdjustmentsToCashFlowsFromOperatingActivities Amortization of (Specify) (footnote details)
5.1	NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription Amortization of debt discount and expense and premium on debt and amortization of loss on reacquired debt	2,924,654	2,785,203
8	DeferredIncomeTaxesNet Deferred Income Taxes (Net)	58,773,258	5,230,481
9	InvestmentTaxCreditAdjustmentsNet Investment Tax Credit Adjustment (Net)	1,836,307	554,085
10	NetIncreaseDecreaseInReceivablesOperatingActivities Net (Increase) Decrease in Receivables	10,262,223	1,889,965
11	NetIncreaseDecreaseInInventoryOperatingActivities Net (Increase) Decrease in Inventory	3,317,479	3,505,677
12	NetIncreaseDecreaseInAllowancesInventoryOperatingActivities Net (Increase) Decrease in Allowances Inventory	26,384	41,211
13	NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities Net Increase (Decrease) in Payables and Accrued Expenses	8,588,815	82,069,675
14	NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities Net (Increase) Decrease in Other Regulatory Assets	112,943,072	63,006,579
15	NetIncreaseDecreaseInOtherRegulatoryLiabilitiesOperatingActivities Net Increase (Decrease) in Other Regulatory Liabilities	32,356,159	74,400,316
16	AllowanceForOtherFundsUsedDuringConstructionOperatingActivities (Less) Allowance for Other Funds Used During Construction	8,101,351	6,725,874
17	UndistributedEarningsFromSubsidiaryCompaniesOperatingActivities (Less) Undistributed Earnings from Subsidiary Companies
18	OtherAdjustmentsToCashFlowsFromOperatingActivities Other (provide details in footnote):
18.1	OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription Other working capital	1,939,790	562,586
18.2	OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription Other	17,749,280	20,393,756
22	NetCashFlowFromOperatingActivities Net Cash Provided by (Used in) Operating Activities (Total of Lines 2 thru 21)	350,965,526	300,314,081
24	CashFlowsFromInvestmentActivitiesAbstract Cash Flows from Investment Activities:
25	ConstructionAndAcquisitionOfPlantIncludingLandAbstract Construction and Acquisition of Plant (including land):
26	GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities Gross Additions to Utility Plant (less nuclear fuel)	654,351,606	555,287,461
27	GrossAdditionsToNuclearFuelInvestingActivities Gross Additions to Nuclear Fuel
28	GrossAdditionsToCommonUtilityPlantInvestingActivities Gross Additions to Common Utility Plant
29	GrossAdditionsToNonutilityPlantInvestingActivities Gross Additions to Nonutility Plant
30	AllowanceForOtherFundsUsedDuringConstructionInvestingActivities (Less) Allowance for Other Funds Used During Construction	8,101,351	6,725,874
31	OtherConstructionAndAcquisitionOfPlantInvestmentActivities Other (provide details in footnote):
31.1	OtherConstructionAndAcquisitionOfPlantInvestmentActivitiesDescription Payment for Purchase of Assets		28,612,204
34	CashOutflowsForPlant Cash Outflows for Plant (Total of lines 26 thru 33)	646,250,255	577,173,791
36	AcquisitionOfOtherNoncurrentAssets Acquisition of Other Noncurrent Assets (d)
37	ProceedsFromDisposalOfNoncurrentAssets Proceeds from Disposal of Noncurrent Assets (d)
39	InvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies Investments in and Advances to Assoc. and Subsidiary Companies	2,000
40	ContributionsAndAdvancesFromAssociatedAndSubsidiaryCompanies Contributions and Advances from Assoc. and Subsidiary Companies
41	DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompaniesAbstract Disposition of Investments in (and Advances to)
42	DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies Disposition of Investments in (and Advances to) Associated and Subsidiary Companies
44	PurchaseOfInvestmentSecurities Purchase of Investment Securities (a)
45	ProceedsFromSalesOfInvestmentSecurities Proceeds from Sales of Investment Securities (a)
46	LoansMadeOrPurchased Loans Made or Purchased
47	CollectionsOnLoans Collections on Loans
49	NetIncreaseDecreaseInReceivablesInvestingActivities Net (Increase) Decrease in Receivables
50	NetIncreaseDecreaseInInventoryInvestingActivities Net (Increase) Decrease in Inventory
51	NetIncreaseDecreaseInAllowancesHeldForSpeculationInvestingActivities Net (Increase) Decrease in Allowances Held for Speculation
52	NetIncreaseDecreaseInPayablesAndAccruedExpensesInvestingActivities Net Increase (Decrease) in Payables and Accrued Expenses
53	OtherAdjustmentsToCashFlowsFromInvestmentActivities Other (provide details in footnote):
53.1	OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription Changes in money pool receivable - net	40,456,217	44,692,410
53.2	OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription Other	49,048	1,719,432
57	CashFlowsProvidedFromUsedInInvestmentActivities Net Cash Provided by (Used in) Investing Activities (Total of lines 34 thru 55)	686,659,424	530,761,949
59	CashFlowsFromFinancingActivitiesAbstract Cash Flows from Financing Activities:
60	ProceedsFromIssuanceAbstract Proceeds from Issuance of:
61	ProceedsFromIssuanceOfLongTermDebtFinancingActivities Long-Term Debt (b)	398,284,127	165,385,422
62	ProceedsFromIssuanceOfPreferredStockFinancingActivities Preferred Stock
63	ProceedsFromIssuanceOfCommonStockFinancingActivities Common Stock
64	OtherAdjustmentsToCashFlowsFromFinancingActivities Other (provide details in footnote):
66	NetIncreaseInShortTermDebt Net Increase in Short-Term Debt (c)
67	OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Other (provide details in footnote):
70	CashProvidedByOutsideSources Cash Provided by Outside Sources (Total 61 thru 69)	398,284,127	165,385,422
72	PaymentsForRetirementAbstract Payments for Retirement of:
73	PaymentsForRetirementOfLongTermDebtFinancingActivities Long-term Debt (b)
74	PaymentsForRetirementOfPreferredStockFinancingActivities Preferred Stock
75	PaymentsForRetirementOfCommonStockFinancingActivities Common Stock
76	OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities Other (provide details in footnote):
76.1	DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities Other	1,539,205	6,964,455
76.2	DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities Changes in money pool payable - net	16,515,813	16,515,813
76.3	DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities Dividends on common equity		10,000,000
78	NetDecreaseInShortTermDebt Net Decrease in Short-Term Debt (c)
80	DividendsOnPreferredStock Dividends on Preferred Stock
81	DividendsOnCommonStock Dividends on Common Stock
83	CashFlowsProvidedFromUsedInFinancingActivities Net Cash Provided by (Used in) Financing Activities (Total of lines 70 thru 81)	383,307,519	178,865,690
85	NetIncreaseDecreaseInCashAndCashEquivalentsAbstract Net Increase (Decrease) in Cash and Cash Equivalents
86	NetIncreaseDecreaseInCashAndCashEquivalents Net Increase (Decrease) in Cash and Cash Equivalents (Total of line 22, 57 and 83)	47,613,621	51,582,178
88	CashAndCashEquivalents Cash and Cash Equivalents at Beginning of Period	10,613	51,592,791
90	CashAndCashEquivalents Cash and Cash Equivalents at End of Period	47,624,234	10,613

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

NOTES TO FINANCIAL STATEMENTS

Use the space below for important notes regarding the Balance Sheet, Statement of Income for the year, Statement of Retained Earnings for the year, and Statement of Cash Flows, or any account thereof. Classify the notes according to each basic statement, providing a subheading for each statement except where a note is applicable to more than one statement.
Furnish particulars (details) as to any significant contingent assets or liabilities existing at end of year, including a brief explanation of any action initiated by the Internal Revenue Service involving possible assessment of additional income taxes of material amount, or of a claim for refund of income taxes of a material amount initiated by the utility. Give also a brief explanation of any dividends in arrears on cumulative preferred stock.
For Account 116, Utility Plant Adjustments, explain the origin of such amount, debits and credits during the year, and plan of disposition contemplated, giving references to Cormmission orders or other authorizations respecting classification of amounts as plant adjustments and requirements as to disposition thereof.
Where Accounts 189, Unamortized Loss on Reacquired Debt, and 257, Unamortized Gain on Reacquired Debt, are not used, give an explanation, providing the rate treatment given these items. See General Instruction 17 of the Uniform System of Accounts.
Give a concise explanation of any retained earnings restrictions and state the amount of retained earnings affected by such restrictions.
If the notes to financial statements relating to the respondent company appearing in the annual report to the stockholders are applicable and furnish the data required by instructions above and on pages 114-121, such notes may be included herein.
For the 3Q disclosures, respondent must provide in the notes sufficient disclosures so as to make the interim information not misleading. Disclosures which would substantially duplicate the disclosures contained in the most recent FERC Annual Report may be omitted.
For the 3Q disclosures, the disclosures shall be provided where events subsequent to the end of the most recent year have occurred which have a material effect on the respondent. Respondent must include in the notes significant changes since the most recently completed year in such items as: accounting principles and practices; estimates inherent in the preparation of the financial statements; status of long-term contracts; capitalization including significant new borrowings or modifications of existing financing agreements; and changes resulting from business combinations or dispositions. However were material contingencies exist, the disclosure of such matters shall be provided even though a significant change since year end may not have occurred.
Finally, if the notes to the financial statements relating to the respondent appearing in the annual report to the stockholders are applicable and furnish the data required by the above instructions, such notes may be included herein.

A. CASH FLOW STATEMENT, ADDITIONAL INFORMATION:

Cash and Cash Equivalents at December 31, 2021

Cash (Account 131) $28,264

Temporary Cash Investments (Account 136) 47,595,970

---------------

Total $47,624,234

=========

SUPPLEMENTAL DISCLOSURE OF CASH FLOW STATEMENT (in 000s)

Cash paid (received) during the period for:

Interest $75,745

Income Taxes ($19,673)

B. FERC FORM 1 PRESENTATION COMPARED TO GENERALLY ACCEPTED ACCOUNTING PRINCIPLES

The accompanying financial statements have been prepared in accordance with the accounting requirements of the FERC as set forth in the Uniform System of Accounts and accounting releases, which differs from GAAP. Additional comparative data, including the 2020 data for the statement of retained earnings and cash flows, are needed to present the financial position and results of operations in order to satisfy GAAP. In addition, GAAP requires the disclosure of the current and long-term portion of assets and liabilities. In accordance with FERC reporting requirements, the aforementioned disclosures were not included in these financial statements.

As required by the FERC, Entergy Mississippi classifies certain items in the income statement (primarily the classification of operating expenses and other deductions) and in the balance sheet (primarily the classification of the components of accumulated deferred income taxes, taxes accrued, certain other miscellaneous current and accrued liabilities, maturities of long-term debt, deferred debits, deferred credits, plant in service, and accumulated depreciation) in a manner different than that required by GAAP.

C. The Notes to the Financial Statements included herein are adapted from the Entergy Corporation and subsidiaries Form 10-K for the Year Ended December 31, 2021. The Form 10-K Notes to the Financial Statements are prepared in conformity with GAAP, and thus may differ in certain instances from the financial statements contained herein.

"Entergy" when used in these Notes means Entergy Corporation and its direct and indirect subsidiaries.

"Registrant Subsidiaries" when used in these Notes means Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, Entergy New Orleans, LLC, Entergy Texas, Inc., and System Energy Resources, Inc.

"Utility" when used in the Notes means Entergy's business segment that generates, transmits, distributes, and sells electric power, with a small amount of natural gas distribution.

"Utility operating companies" when used in these Notes means Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas.

NOTE 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Use of Estimates in the Preparation of Financial Statements

In conformity with generally accepted accounting principles in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used.

Property, Plant, and Equipment

Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens.

Details of property, plant, and equipment by functional category are presented on FERC Form 1 pages 204-207 and details of accumulated depreciation by functional category are presented on FERC Form 1 page 219.

Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
2021	2.7%	2.4%	3.6%	3.2%	3.2%	1.9%
2020	2.6%	2.4%	3.5%	3.1%	3.1%	2.1%
2019	2.5%	2.4%	3.2%	3.2%	3.0%	2.1%

As of December 31, 2021, construction expenditures included in accounts payable are $35.6 million for Entergy Arkansas, $507.9 million for Entergy Louisiana, $26.5 million for Entergy Mississippi, $73.1 million for Entergy Texas, and $23.4 million for System Energy. As of December 31, 2020, construction expenditures included in accounts payable are $59.7 million for Entergy Arkansas, $460.5 million for Entergy Louisiana, $31.4 million for Entergy Mississippi, $9.2 million for Entergy New Orleans, $116.8 million for Entergy Texas, and $17.7 million for System Energy.

Jointly-Owned Generating Stations

Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2021, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows:


Generating Stations		Fuel Type	Total Megawatt Capability (a)	Ownership	Investment	Accumulated Depreciation
					(In Millions)
Utility business:
Entergy Arkansas -
Independence	Unit 1	Coal	822	31.50%	$143	$106
Independence	Common Facilities	Coal		15.75%	$43	$31
White Bluff	Units 1 and 2	Coal	1,639	57.00%	$587	$390
Ouachita (b)	Common Facilities	Gas		66.67%	$173	$156
Union (c)	Common Facilities	Gas		25.00	$29	$9
Entergy Louisiana -
Roy S. Nelson	Unit 6	Coal	521	40.25%	$294	$212
Roy S. Nelson	Unit 6 Common Facilities	Coal		19.57%	$21	$10
Big Cajun 2	Unit 3	Coal	540	24.15%	$151	$131
Big Cajun 2	Unit 3 Common Facilities	Coal		8.05%	$5	$3
Ouachita (b)	Common Facilities	Gas		33.33%	$91	$78
Acadia	Common Facilities	Gas		50.00%	$21	$2
Union (c)	Common Facilities	Gas		50.00	$59	$10
Entergy Mississippi -
Independence	Units 1 and 2 and Common Facilities	Coal	1,246	25.00%	$286	$179
Entergy New Orleans -
Union (c)	Common Facilities	Gas		25.00	$29	$8
Entergy Texas -
Roy S. Nelson	Unit 6	Coal	521	29.75%	$208	$120
Roy S. Nelson	Unit 6 Common Facilities	Coal		14.47%	$7	$3
Big Cajun 2	Unit 3	Coal	540	17.85%	$113	$84
Big Cajun 2	Unit 3 Common Facilities	Coal		5.95%	$4	$1
Montgomery County	Unit 1	Gas	909	92.44%	$728	$18
System Energy -
Grand Gulf (d)	Unit 1	Nuclear	1,404	90.00	$5,363	$3,317

a.“Total Megawatt Capability” is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize.

b.Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units.

c.Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units.

d.Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements.

Allowance for Funds Used During Construction (AFUDC)

AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers.

Income Taxes

Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. In September 2019, Entergy Utility Holding Company, LLC and its regulated wholly-owned subsidiaries including Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, and Entergy New Orleans, LLC became eligible to join and joined the Entergy Corporation consolidated federal income tax group. These changes do not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward.

Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “Other Tax Matters - Tax Cuts and Jobs Act” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017.

The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment.

Accounting for the Effects of Regulation

Entergy’s Utility operating companies and System Energy are rate-regulated enterprises whose rates meet three criteria specified in accounting standards. The Utility operating companies and System Energy have rates that (i) are approved by a body (its regulator) empowered to set rates that bind customers; (ii) are cost-based; and (iii) can be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Because the Utility operating companies and System Energy meet these criteria, each of them capitalizes costs that would otherwise be charged to expense if the rate actions of its regulator make it probable that those costs will be recovered in future revenue. Such capitalized costs are reflected as regulatory assets in the accompanying financial statements. When an enterprise concludes that recovery of a regulatory asset is no longer probable, the regulatory asset must be removed from the entity’s balance sheet.

An enterprise that ceases to meet the three criteria for all or part of its operations should report that event in its financial statements. In general, the enterprise no longer meeting the criteria should eliminate from its balance sheet all regulatory assets and liabilities related to the applicable operations. Additionally, if it is determined that a regulated enterprise is no longer recovering all of its costs, it is possible that an impairment may exist that could require further write-offs of plant assets.

Regulatory Asset or Liability for Income Taxes

Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or returned to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements.

Cash and Cash Equivalents

Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents.

Allowance for Doubtful Accounts

The allowance for doubtful accounts reflects Entergy’s best estimate of losses on the accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. Utility operating company customer accounts receivable are written off consistent with approved regulatory requirements.

Equity Method Investments

Entergy owns investments that are accounted for under the equity method of accounting because Entergy’s ownership level results in significant influence, but not control, over the investee and its operations. Entergy records its share of the investee’s comprehensive earnings and losses in income and as an increase or decrease to the investment account. Any cash distributions are charged against the investment account. Entergy discontinues the recognition of losses on equity investments when its share of losses equals or exceeds its carrying amount for an investee plus any advances made or commitments to provide additional financial support.

Derivative Financial Instruments and Commodity Derivatives

The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries.

Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered.

For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. See Note 15 to the financial statements for further discussion of fair value.

Impairment of Long-lived Assets

Entergy periodically reviews long-lived assets held in all of its business segments whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets.

Reacquired Debt

The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment.

Taxes Imposed on Revenue-Producing Transactions

Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues, unless required to report them differently by a regulatory authority.

NOTE 2. RATE AND REGULATORY MATTERS

Regulatory Assets and Regulatory Liabilities

Regulatory assets represent probable future revenues associated with costs that Entergy expects to recover from customers through the regulatory ratemaking process under which the Utility business operates. Regulatory liabilities represent probable future reductions in revenues associated with amounts that Entergy expects to benefit customers through the regulatory ratemaking process under which the Utility business operates. Details of regulatory assets in FERC account 182.3 are presented on FERC Form 1 page 232. Details of regulatory liabilities in FERC account 254 are presented on FERC Form 1 page 278.

Fuel and purchased power cost recovery

The Utility operating companies are allowed to recover fuel and purchased power costs through fuel mechanisms included in electric and gas rates that are recorded as fuel cost recovery revenues. The difference between revenues collected and the current fuel and purchased power costs is generally recorded as “Deferred fuel costs” on the Utility operating companies’ financial statements. The table below shows the amount of deferred fuel costs as of December 31, 2021 and 2020 that Entergy expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review.


	2021	2020
	(In Millions)
Entergy Arkansas (a)	$177.6	$15.2
Entergy Louisiana (b)	$213.5	$170.4
Entergy Mississippi	$121.9	($14.7)
Entergy New Orleans (b)	($3.5)	$6.2
Entergy Texas	$48.3	($85.4)

a.Includes $68.8 million in 2021 and $68.2 million in 2020 of fuel and purchased power costs whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months.

b.Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months.

Entergy Mississippi

Entergy Mississippi’s rate schedules include an energy cost recovery rider that is adjusted annually to reflect accumulated over- or under-recoveries. Entergy Mississippi’s fuel cost recoveries are subject to annual audits conducted pursuant to the authority of the MPSC.

In November 2018, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation of the annual factor included an under-recovery of approximately $57 million as of September 30, 2018. In January 2019 the MPSC approved the proposed energy cost factor effective for February 2019 bills.

In November 2019, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation included $39.6 million of prior over-recovery flowing back to customers beginning February 2020. Entergy Mississippi’s balance in its deferred fuel account did not decrease as expected after implementation of the new factor. In an effort to assist customers during the

COVID-19 pandemic, in May 2020, Entergy Mississippi requested an interim adjustment to the energy cost recovery rider to credit approximately $50 million from the over-recovered balance in the deferred fuel account to customers over four consecutive billing months. The MPSC approved this interim adjustment in May 2020 effective for June through September 2020 bills.

In November 2020, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation of the annual factor included an over-recovery of approximately $24.4 million as of September 30, 2020. In January 2021 the MPSC approved the proposed energy cost factor effective for February 2021 bills.

In November 2021, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation of the annual factor included an under-recovery of approximately $80.6 million as of September 30, 2021. In December 2021, at the request of the MPSC, Entergy Mississippi submitted a proposal to mitigate the impact of rising fuel costs on customer bills during 2022. Entergy Mississippi proposed that the deferred fuel balance as of December 31, 2021, which was $121.9 million, be amortized over three years, and that the MPSC authorize Entergy Mississippi to apply its weighted-average cost of capital as the carrying cost for the unamortized fuel balance. In January 2022 the MPSC approved the amortization of $100 million of the deferred fuel balance over two years and authorized Entergy Mississippi to apply its weighted-average cost of capital as the carrying cost for the unamortized fuel balance. The MPSC approved the proposed energy cost factor effective for February 2022 bills.

Retail Rate Proceedings

Filings with the MPSC (Entergy Mississippi)

Retail Rates

Formula Rate Plan Revisions

In October 2018, Entergy Mississippi proposed revisions to its formula rate plan that would provide for a mechanism in the formula rate plan, the interim capacity rate adjustment mechanism, to recover the non-fuel related costs of additional owned capacity acquired by Entergy Mississippi, including the non-fuel annual ownership costs of the Choctaw Generating Station, as well as to allow similar cost recovery treatment for other future capacity acquisitions, such as the Sunflower Solar Facility, that are approved by the MPSC. In December 2019 the MPSC approved Entergy Mississippi’s proposed revisions to its formula rate plan to provide for an interim capacity rate adjustment mechanism to recover the $59 million first-year annual revenue requirement associated with the non-fuel ownership costs of the Choctaw Generating Station, which Entergy Mississippi began billing in January 2020. The MPSC must approve recovery through the interim capacity rate adjustment for each new resource. In addition, the MPSC approved revisions to the formula rate plan which allows Entergy Mississippi to begin billing rate adjustments effective April 1 of the filing year on a temporary basis subject to refund or credit to customers, subject to final MPSC order. The MPSC also authorized Entergy Mississippi to remove vegetation management costs from the formula rate plan and recover these costs through the establishment of a vegetation management rider. Effective with the April 2020 billing cycle, Entergy Mississippi implemented a rider to recover $22 million in vegetation management costs.

2019 Formula Rate Plan Filing

In March 2019, Entergy Mississippi submitted its formula rate plan 2019 test year filing and 2018 look-back filing showing Entergy Mississippi’s earned return for the historical 2018 calendar year to be above the

formula rate plan bandwidth and projected earned return for the 2019 calendar year to be below the formula rate plan bandwidth. The 2019 test year filing shows a $36.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.94% return on rate base, within the formula rate plan bandwidth. The 2018 look-back filing compares actual 2018 results to the approved benchmark return on rate base and shows a $10.1 million interim decrease in formula rate plan revenues is necessary. In the fourth quarter 2018, Entergy Mississippi recorded a provision of $9.3 million that reflected the estimate of the difference between the 2018 expected earned rate of return on rate base and an established performance-adjusted benchmark rate of return under the formula rate plan performance-adjusted bandwidth mechanism. In the first quarter 2019, Entergy Mississippi recorded a $0.8 million increase in the provision to reflect the amount shown in the look-back filing. In June 2019, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed that the 2019 test year filing showed that a $32.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.93% return on rate base, within the formula rate plan bandwidth. Additionally, pursuant to the joint stipulation, Entergy Mississippi’s 2018 look-back filing reflected an earned return on rate base of 7.81% in calendar year 2018 which is above the look-back benchmark return on rate base of 7.13%, resulting in an $11 million decrease in formula rate plan revenues on an interim basis through May 2020. In the second quarter 2019, Entergy Mississippi recorded an additional $0.9 million increase in the provision to reflect the $11 million shown in the look-back filing. In June 2019 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2019.

2020 Formula Rate Plan Filing

In March 2020, Entergy Mississippi submitted its formula rate plan 2020 test year filing and 2019 look-back filing showing Entergy Mississippi’s earned return for the historical 2019 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2020 calendar year to be below the formula rate plan bandwidth. The 2020 test year filing shows a $24.6 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.51% return on rate base, within the formula rate plan bandwidth. The 2019 look-back filing compares actual 2019 results to the approved benchmark return on rate base and reflects the need for a $7.3 million interim increase in formula rate plan revenues. In accordance with the MPSC-approved revisions to the formula rate plan, Entergy Mississippi implemented a $24.3 million interim rate increase, reflecting a cap equal to 2% of 2019 retail revenues, effective with the April 2020 billing cycle, subject to refund. In June 2020, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed that the 2020 test year filing showed that a $23.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.51% return on rate base, within the formula rate plan bandwidth. Pursuant to the joint stipulation, Entergy Mississippi’s 2019 look-back filing reflected an earned return on rate base of 6.75% in calendar year 2019, which is within the look-back bandwidth. As a result, there is no change in formula rate plan revenues in the 2019 look-back filing. In June 2020 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2020. In the June 2020 order the MPSC directed Entergy Mississippi to submit revisions to its formula rate plan to realign recovery of costs from its energy efficiency cost recovery rider to its formula rate plan. In November 2020 the MPSC approved Entergy Mississippi’s revisions to its formula rate plan providing for the realignment of energy efficiency costs to its formula rate plan, the deferral of energy efficiency expenditures into a regulatory asset, and the elimination of its energy efficiency cost recovery rider effective with the January 2022 billing cycle.

2021 Formula Rate Plan Filing

In March 2021, Entergy Mississippi submitted its formula rate plan 2021 test year filing and 2020 look-back filing showing Entergy Mississippi’s earned return for the historical 2020 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2021 calendar year to be below the formula rate plan bandwidth. The 2021 test year filing shows a $95.4 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.69% return on rate base, within the formula rate plan bandwidth. The change in formula rate plan revenues, however, is capped at 4% of retail revenues, which equates to a revenue change of $44.3 million. The 2021 evaluation report also includes $3.9 million in demand side management costs for which the MPSC approved realignment of recovery from the energy efficiency rider to the formula rate plan. These costs are not subject to the 4% cap and result in a total change in formula rate plan revenues of $48.2 million. The 2020 look-back filing compares actual 2020 results to the approved benchmark return on rate base and reflects the need for a $16.8 million interim increase in formula rate plan revenues. In addition, the 2020 look-back filing includes an interim capacity adjustment true-up for the Choctaw Generating Station, which increases the look-back interim rate adjustment by $1.7 million. These interim rate adjustments total $18.5 million. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $22.1 million interim rate increase, reflecting a cap equal to 2% of 2020 retail revenues, effective with the April 2021 billing cycle, subject to refund, pending a final MPSC order. The $3.9 million of demand side management costs and the Choctaw Generating Station true-up of $1.7 million, which are not subject to the 2% cap of 2020 retail revenues, were included in the April 2021 rate adjustments.

In June 2021, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2021 test year filing that resulted in a total rate increase of $48.2 million. Pursuant to the joint stipulation, Entergy Mississippi’s 2020 look-back filing reflected an earned return on rate base of 6.12% in calendar year 2020, which is below the look-back bandwidth, resulting in a $17.5 million increase in formula rate plan revenues on an interim basis through June 2022. This includes $1.7 million related to the Choctaw Generating Station and $3.7 million of COVID-19 non-bad debt expenses. See “COVID-19 Orders” below for additional discussion of provisions of the joint stipulation related to COVID-19 expenses. In June 2021 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2021. In June 2021, Entergy Mississippi recorded regulatory credits of $19.9 million to reflect the effects of the joint stipulation.

2022 Formula Rate Plan Filing

Entergy Mississippi’s formula rate plan includes a look-back evaluation report filing in March 2022 that will compare actual 2021 results to the performance-adjusted allowed return on rate base. In fourth quarter 2021, Entergy Mississippi recorded a regulatory asset of $19 million in connection with the look-back feature of the formula rate plan to reflect that the 2021 earned return was below the formula bandwidth.

COVID-19 Orders

In March 2020 the MPSC issued an order suspending disconnections for a period of sixty days. The MPSC extended the order on disconnections through May 26, 2020. In April 2020 the MPSC issued an order authorizing utilities to defer incremental costs and expenses associated with COVID-19 compliance and to seek future recovery through rates of the prudently incurred incremental costs and expenses. In December 2020, Entergy Mississippi resumed disconnections for commercial, industrial, and governmental customers with past-due balances that have not made payment arrangements. In January 2021, Entergy Mississippi resumed disconnecting service for residential customers with past-due balances that had not made payment arrangements. Pursuant to the June 2021 MPSC order approving Entergy Mississippi’s 2021 formula rate plan filing, Entergy Mississippi stopped deferring COVID-19 non-bad debt expenses effective December 31, 2020 and included those expenses in the look-back filing for the 2021 formula rate plan test year. In the order, the MPSC also adopted

Entergy Mississippi’s quantification and methodology for calculating COVID-19 incremental bad debt expenses and authorized Entergy Mississippi to continue deferring these bad debt expenses through December 2021. As of December 31, 2021, Entergy Mississippi had a regulatory asset of $15 million for costs associated with the COVID-19 pandemic.

Entergy Arkansas Opportunity Sales Proceeding

In June 2009 the LPSC filed a complaint requesting that the FERC determine that certain of Entergy Arkansas’s sales of electric energy to third parties: (a) violated the provisions of the System Agreement that allocated the energy generated by Entergy System resources; (b) imprudently denied the Entergy System and its ultimate consumers the benefits of low-cost Entergy System generating capacity; and (c) violated the provision of the System Agreement that prohibited sales to third parties by individual companies absent an offer of a right-of-first-refusal to other Utility operating companies. The LPSC’s complaint challenged sales made beginning in 2002 and requested refunds. In July 2009 the Utility operating companies filed a response to the complaint arguing among other things that the System Agreement contemplates that the Utility operating companies may make sales to third parties for their own account, subject to the requirement that those sales be included in the load (or load shape) for the applicable Utility operating company. The FERC subsequently ordered a hearing in the proceeding.

After a hearing, the ALJ issued an initial decision in December 2010. The ALJ found that the System Agreement allowed for Entergy Arkansas to make the sales to third parties but concluded that the sales should be accounted for in the same manner as joint account sales. The ALJ concluded that “shareholders” should make refunds of the damages to the Utility operating companies, along with interest. Entergy disagreed with several aspects of the ALJ’s initial decision and in January 2011 filed with the FERC exceptions to the decision.

The FERC issued a decision in June 2012 and held that, while the System Agreement is ambiguous, it does provide authority for individual Utility operating companies to make opportunity sales for their own account and Entergy Arkansas made and priced these sales in good faith. The FERC found, however, that the System Agreement does not provide authority for an individual Utility operating company to allocate the energy associated with such opportunity sales as part of its load but provides a different allocation authority. The FERC further found that the after-the-fact accounting methodology used to allocate the energy used to supply the sales was inconsistent with the System Agreement. The FERC in its decision established further hearing procedures to quantify the effect of repricing the opportunity sales in accordance with the FERC’s June 2012 decision. The hearing was held in May 2013 and the ALJ issued an initial decision in August 2013. The LPSC, the APSC, the City Council, and FERC staff filed briefs on exceptions and/or briefs opposing exceptions. Entergy filed a brief on exceptions requesting that the FERC reverse the initial decision and a brief opposing certain exceptions taken by the LPSC and FERC staff.

In April 2016 the FERC issued orders addressing requests for rehearing filed in July 2012 and the ALJ’s August 2013 initial decision. The first order denied Entergy’s request for rehearing and affirmed the FERC’s earlier rulings that Entergy’s original methodology for allocating energy costs to the opportunity sales was incorrect and, as a result, Entergy Arkansas must make payments to the other Utility operating companies to put them in the same position that they would have been in absent the incorrect allocation. The FERC clarified that interest should be included with the payments. The second order affirmed in part, and reversed in part, the rulings in the ALJ’s August 2013 initial decision regarding the methodology that should be used to calculate the payments Entergy Arkansas is to make to the other Utility operating companies. The FERC affirmed the ALJ’s ruling that a full re-run of intra-system bills should be performed but required that methodology be modified so that the sales have the same priority for purposes of energy allocation as joint account sales. The FERC reversed the ALJ’s decision that any payments by Entergy Arkansas should be reduced by 20%. The FERC also reversed

the ALJ’s decision that adjustments to other System Agreement service schedules and excess bandwidth payments should not be taken into account when calculating the payments to be made by Entergy Arkansas. The FERC held that such adjustments and excess bandwidth payments should be taken into account but ordered further proceedings before an ALJ to address whether a cap on any reduction due to bandwidth payments was necessary and to implement the other adjustments to the calculation methodology.

In May 2016, Entergy Services filed a request for rehearing of the FERC’s April 2016 order arguing that payments made by Entergy Arkansas should be reduced as a result of the timing of the LPSC’s approval of certain contracts. Entergy Services also filed a request for clarification and/or rehearing of the FERC’s April 2016 order addressing the ALJ’s August 2013 initial decision. The APSC and the LPSC also filed requests for rehearing of the FERC’s April 2016 order. In September 2017 the FERC issued an order denying the request for rehearing on the issue of whether any payments by Entergy Arkansas to the other Utility operating companies should be reduced due to the timing of the LPSC’s approval of Entergy Arkansas’s wholesale baseload contract with Entergy Louisiana. In November 2017 the FERC issued an order denying all of the remaining requests for rehearing of the April 2016 order. In November 2017, Entergy Services filed a petition for review in the D.C. Circuit of the FERC’s orders in the first two phases of the opportunity sales case. In December 2017 the D.C. Circuit granted Entergy Services’ request to hold the appeal in abeyance pending final resolution of the related proceeding before the FERC. In January 2018 the APSC and the LPSC filed separate petitions for review in the D.C. Circuit, and the D.C. Circuit consolidated the appeals with Entergy Services’ appeal.

The hearing required by the FERC’s April 2016 order was held in May 2017. In July 2017 the ALJ issued an initial decision addressing whether a cap on any reduction due to bandwidth payments was necessary and whether to implement the other adjustments to the calculation methodology. In August 2017 the Utility operating companies, the LPSC, the APSC, and FERC staff filed individual briefs on exceptions challenging various aspects of the initial decision. In September 2017 the Utility operating companies, the LPSC, the APSC, the MPSC, the City Council, and FERC staff filed separate briefs opposing exceptions taken by various parties.

Based on testimony previously submitted in the case and its assessment of the April 2016 FERC orders, in the first quarter 2016, Entergy Arkansas recorded a liability of $87 million, which included interest, for its estimated increased costs and payment to the other Utility operating companies, and a deferred fuel regulatory asset of $75 million. Following its assessment of the course of the proceedings, including the FERC’s denial of rehearing in November 2017 described above, in the fourth quarter 2017, Entergy Arkansas recorded an additional liability of $35 million and a regulatory asset of $31 million.

In October 2018 the FERC issued an order addressing the ALJ’s July 2017 initial decision. The FERC reversed the ALJ’s decision to cap the reduction in Entergy Arkansas’s payment to account for the increased bandwidth payments that Entergy Arkansas made to the other operating companies. The FERC also reversed the ALJ’s decision that Grand Gulf sales from January through September 2000 should be included in the calculation of Entergy Arkansas’s payment. The FERC affirmed on other grounds the ALJ’s rejection of the LPSC’s claim that certain joint account sales should be accounted for as part of the calculation of Entergy Arkansas’s payment. In November 2018 the LPSC requested rehearing of the FERC’s October 2018 decision. In December 2019 the FERC denied the LPSC’s request for rehearing. In January 2020 the LPSC appealed the December 2019 decision to the D.C. Circuit.

In December 2018, Entergy made a compliance filing in response to the FERC’s October 2018 order. The compliance filing provided a final calculation of Entergy Arkansas’s payments to the other Utility operating companies, including interest. No protests were filed in response to the December 2018 compliance filing. The

December 2018 compliance filing is pending FERC action. Refunds and interest in the following amounts were paid by Entergy Arkansas to the other operating companies in December 2018:


	Total refunds including interest
	Payment/(Receipt)
	(In Millions)
	Principal	Interest	Total
Entergy Arkansas	$68	$67	$135
Entergy Louisiana	($30)	($29)	($59)
Entergy Mississippi	($18)	($18)	($36)
Entergy New Orleans	($3)	($4)	($7)
Entergy Texas	($17)	($16)	($33)

As described above, the FERC’s opportunity sales orders have been appealed to the D.C. Circuit. In February 2020 all of the appeals were consolidated and in April 2020 the D.C. Circuit established a briefing schedule. Briefing was completed in September 2020 and oral argument was heard in December 2020. In July 2021 the D.C. Circuit issued a decision denying all of the petitions for review filed in response to the FERC’s opportunity sales orders.

In February 2019 the LPSC filed a new complaint relating to two issues that were raised in the opportunity sales proceeding, but that, in its October 2018 order, the FERC held were outside the scope of the proceeding. In March 2019, Entergy Services filed an answer and motion to dismiss the new complaint. In November 2019 the FERC issued an order denying the LPSC’s complaint. The order concluded that the settlement agreement approved by the FERC in December 2015 terminating the System Agreement barred the LPSC’s new complaint. In December 2019 the LPSC requested rehearing of the FERC’s November 2019 order, and in July 2020 the FERC issued an order dismissing the LPSC’s request for rehearing. In September 2020 the LPSC appealed to the D.C. Circuit the FERC’s orders dismissing the new opportunity sales complaint. In November 2020 the D.C. Circuit issued an order establishing that briefing will occur in January 2021 through April 2021. Oral argument was held in September 2021. In December 2021 the D.C. Circuit denied the LPSC’s Petition for Review of the new opportunity sales complaint. The opportunity sales cases are complete at FERC and at the D.C. Circuit and no additional refund amounts are owed by Entergy Arkansas.

Storm Cost Recovery Filings with Retail Regulators

Entergy Mississippi

Entergy Mississippi has approval from the MPSC to collect a storm damage provision of $1.75 million per month. If Entergy Mississippi’s accumulated storm damage provision balance exceeds $15 million, the collection of the storm damage provision ceases until such time that the accumulated storm damage provision becomes less than $10 million. Entergy Mississippi’s storm damage provision balance has been less than $10 million since May 2019, and Entergy Mississippi has been billing the monthly storm damage provision since July 2019.

NOTE 3. INCOME TAXES

Details regarding income taxes are presented on FERC Form 1 pages 261-267 and 272-277.

Carryovers

The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2021 are as follows:

Entergy Arkansas

Entergy Louisiana

Entergy Mississippi

Entergy New Orleans

Entergy Texas

System Energy

Federal net operating losses before 1/1/2018

$— billion

$1.7 billion

$— billion

$0.9 billion

$— billion

Year(s) of expiration

N/A

2035-2037

N/A

2037

N/A

Federal net operating losses - 1/1/2018 forward

$4.5 billion

$2.1 billion

$0.7 billion

$2.6 billion

$— billion

Year(s) of expiration

N/A

State net operating losses

$4.8 billion

$7.2 billion

$2.3 billion

$1.7 billion

$— million

Year(s) of expiration

2023-2026

N/A

2038-2041

N/A

Misc. federal credits

$4.7 million

$12.3 million

$1.8 million

$15.3 million

$3.1 million

$1.5 million

Year(s) of expiration

2038-2041

2035-2041

2038-2041

2037-2041

2036-2041

State credits

$— million

$1.3 million

$—million

$2.9 million

$9 million

Year(s) of expiration

N/A

2022-2025

N/A

2027

2022-2025

As a result of the accounting for uncertain tax positions, the amount of the deferred tax assets reflected in the financial statements is less than the amount of the tax effect of the federal and state net operating loss carryovers and tax credit carryovers.

Unrecognized tax benefits

Accounting standards establish a “more-likely-than-not” recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded.

A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2021, 2020, and 2019 is as follows:


2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Gross balance at January 1, 2021	$1,364,635	$640,295	$549,717	$639,546	$521,932	$21,652
Additions based on tax positions related to the current year	30,419	13,437	684	1,050	32,616	1,753
Additions for tax positions of prior years	15,013	9,304	1,504	6	2,315	1,897
Reductions for tax positions of prior years	(1,573)	(58,408)	(2,336)	(1,105)	(4,568)	(1,946)
Gross balance at December 31, 2021	1,408,494	604,628	549,569	639,497	552,295	23,356


Offsets to gross unrecognized tax benefits:
Loss and tax credit carryovers	(992,643)	(604,628)	(388,728)	(484,899)	(540,694)	(8,576)
Unrecognized tax benefits net of unused tax attributes and payments	$415,851	$—	$160,841	$154,598	$11,601	$14,780


2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Gross balance at January 1, 2020	$1,341,242	$2,381,653	$566,287	$716,773	$21,406	$473,331
Additions based on tax positions related to the current year (a)	9,403	35,681	5,619	2,430	504,362	4,013
Additions for tax positions of prior years	13,400	10,508	1,156	294	799	4,606
Reductions for tax positions of prior years	(11,346)	(679,601)	(24,173)	(80,267)	(5,559)	(41,466)
Settlements	11,936	(1,107,946)	828	316	924	(418,832)
Gross balance at December 31, 2020	1,364,635	640,295	549,717	639,546	521,932	21,652
Offsets to gross unrecognized tax benefits:
Loss and tax credit carryovers	(1,112,628)	(640,295)	(465,679)	(451,922)	(507,720)	(7,413)
Unrecognized tax benefits net of unused tax attributes and payments	$252,007	$—	$84,038	$187,624	$14,212	$14,239


2019	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Gross balance at January 1, 2019	$1,298,662	$2,400,171	$508,765	$686,687	$17,802	$467,487
Additions based on tax positions related to the current year	84,335	28,705	68,594	40,676	2,312	5,496
Additions for tax positions of prior years	20,399	25,090	1,651	489	1,299	2,186
Reductions for tax positions of prior years	(62,154)	(72,313)	(12,723)	(11,079)	(7)	(1,838)
Gross balance at December 31, 2019	1,341,242	2,381,653	566,287	716,773	21,406	473,331
Offsets to gross unrecognized tax benefits:
Loss and tax credit carryovers	(1,134,187)	(1,573,257)	(506,976)	(445,430)	(3,944)	(8,392)
Unrecognized tax benefits net of unused tax attributes and payments	$207,055	$808,396	$59,311	$271,343	$17,462	$464,939

a.The primary additions for Entergy Texas in 2020 are related to the mark-to-market treatment discussed in “Other Tax Matters - Tax Accounting Methods” below.

The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows:


December 31,
2021	2020	2019
(In Millions)


Entergy Arkansas	$262.1	$259.3	$203.3
Entergy Louisiana	$66.3	$63.8	$556.3
Entergy Mississippi	$51.7	$50.7	$1.9
Entergy New Orleans	$228.6	$203.5	$242.7
Entergy Texas	$2.6	$6.1	$5.7
System Energy	$1.7	$0.5	$—

Accrued balances for the possible payment of interest related to unrecognized tax benefits are as follows:


	December 31,
	2021	2020	2019
	(In Millions)
Entergy Arkansas	$2.7	$2.3	$3.1
Entergy Louisiana	$3.7	$3.4	$14.2
Entergy Mississippi	$2.4	$1.9	$1.7
Entergy New Orleans	$5.2	$3.9	$4.7
Entergy Texas	$1.1	$0.9	$1.1
System Energy	$12.1	$11.9	$14.5

The Registrant Subsidiaries record interest and penalties related to unrecognized tax benefits in income tax expense. No penalties were recorded in 2021, 2020, and 2019. Interest (net-of-tax) was recorded as follows:


	2021	2020	2019
	(In Millions)
Entergy Arkansas	$0.4	($0.8)	$1.4
Entergy Louisiana	$0.3	($10.8)	($3.7)
Entergy Mississippi	$0.5	$0.2	$0.5
Entergy New Orleans	$1.3	($0.8)	$2.0
Entergy Texas	$0.2	($0.2)	$0.2
System Energy	$0.2	($2.6)	$1.3

Income Tax Audits

Entergy and its subsidiaries file U.S. federal and various state income tax returns. IRS examinations are complete for years before 2016. All state taxing authorities’ examinations are complete for years before 2014. Entergy regularly defends its positions and works with the IRS to resolve audits. The resolution of audit issues could result in significant changes to the amounts of unrecognized tax benefits in the next twelve months.

2014-2015 IRS Audit

The IRS completed its examination of the 2014 and 2015 tax years and issued its 2014-2015 RAR in November 2020. Entergy agreed to all proposed adjustments contained in the RAR. Entergy and the Registrant Subsidiaries recorded the effects of the adjustments associated with the audit in 2020.

Additional effects of the completion of the 2014-2015 IRS tax audit are discussed below within Tax Accounting Methods.

Other Tax Matters

Tax Cuts and Jobs Act (TCJA)

The most significant effect of the TCJA for Entergy and the Registrant Subsidiaries was the change in the federal corporate income tax rate from 35% to 21%, effective January 1, 2018.

TCJA also limited the deduction for net business interest expense to 30 percent of adjusted taxable income, which is similar to earnings before interest, taxes, depreciation, and amortization. The limitation does not apply to interest expense that is properly allocable to a trade or business classified as a regulated public utility. This was further modified by a temporary provision of the CARES Act resulting in an increase of the adjusted taxable income limitation from 30% to 50% for tax years that begin in 2019 or 2020.

The IRS issued final regulations which are effective for Entergy beginning with the 2021 tax year. The regulations provide that if 90% of a tax group’s consolidated assets consist of regulated utility property, the entire consolidated tax group will be treated as a regulated public utility and all of the consolidated group’s interest expense will be currently tax deductible. Entergy expects that this provision will continue to apply to Entergy’s business operations making the application of this limitation to Entergy less likely. The provision has not resulted in Entergy having to report any significant business interest expense limitations on its tax returns.

With respect to the federal corporate income tax rate change from 35% to 21% in 2017, Entergy and the Registrant Subsidiaries recorded a regulatory liability associated with the decrease in the net accumulated deferred income tax liability, which is often referred to as “excess ADIT,” a significant portion of which has been paid to customers in 2019, 2020 and 2021 in the form of lower rates. Entergy’s December 31, 2021 and December 31, 2020 balance sheets reflect a regulatory liability of $1.3 billion and $1.6 billion, respectively, as a result of the re-measurement of deferred tax assets and liabilities from the income tax rate change, amortization of excess ADIT, and payments to customers during 2019, 2020 and 2021. Entergy’s regulatory liability for income taxes includes a gross-up at the applicable tax rate because of the effect that excess ADIT has on the ratemaking formula. The regulatory liability for income taxes includes the effect of a) the reduction of the net deferred tax liability resulting in excess ADIT, and b) the tax gross-up of excess ADIT. The Registrant Subsidiaries’ December 31, 2021 and December 31, 2020 balance sheets reflect net regulatory liabilities for income taxes as follows:


	2021	2020
	(In Millions)
Entergy Arkansas	$432	$467
Entergy Louisiana	$338	$479
Entergy Mississippi	$212	$224
Entergy New Orleans	$42	$59
Entergy Texas	$171	$205
System Energy	$113	$152

Excess ADIT is generally classified into two categories: 1) the portion that is subject to the normalization requirements of the TCJA, i.e., “protected”, and 2) the portion that is not subject to such normalization provisions, referred to as “unprotected”. The TCJA provides that the normalization method of accounting for income taxes is required for excess ADIT associated with public utility property. The TCJA provides for the use of the average

rate assumption method (ARAM) for the determination of the timing of the return of excess ADIT associated with such property. Under ARAM, the excess ADIT is reduced over the remaining life of the asset. Remaining asset lives vary for each Registrant Subsidiary, but the average life of public utility property is typically 30 years or longer. Entergy will amortize the protected portion of the excess ADIT in conformity with the normalization requirements. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes protected excess ADIT as follows:


	2021	2020
	(In Millions)
Entergy Arkansas	$463	$490
Entergy Louisiana	$669	$721
Entergy Mississippi	$237	$248
Entergy New Orleans	$56	$61
Entergy Texas	$208	$215
System Energy	$148	$173

Payment of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This has a significant effect on the effective tax rate for the period as compared to the statutory tax rate. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes unprotected excess ADIT as follows:


	2021	2020
	(In Millions)
Entergy Arkansas	$12	$11
Entergy Louisiana	$148	$223
Entergy New Orleans	$—	$3
Entergy Texas	$26	$54
System Energy	$—	$16

The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows for 2021 and 2020:


	2021	2020
	(In Millions)
Entergy	$88	$74
Entergy Arkansas	$8	$8
Entergy Louisiana	$33	$31
Entergy New Orleans	$1	$6
Entergy Texas	$28	$29
System Energy	$18	$—

In addition to the protected and unprotected excess ADIT amounts, the net regulatory liability for income taxes includes other regulatory assets and liabilities for income taxes associated with AFUDC, which is described in Note 1 to the financial statements.

Included in the effect of the computation of the changes in deferred tax assets and liabilities is the recognition threshold and measurement of uncertain tax positions resulting in unrecognized tax benefits. The

final economic outcome of such unrecognized tax benefits is generally the result of a negotiated settlement with the IRS that often differs from the amount that is recorded as realizable under GAAP. The intrinsic uncertainty with respect to all such tax positions means that the difference between current estimates of such amounts likely to be realized and actual amounts realized upon settlement may have an effect on income tax expense and the regulatory liability for income taxes in future periods.

Entergy anticipates that the effect of TCJA may continue to have ramifications that require adjustments in the future as certain events occur. These events include: 1) IRS audit adjustments to or amendments of federal and state income tax returns that include modifications to the computation of taxable income resulting from TCJA; and 2) additional guidance, interpretations, or rulings by the U.S. Department of the Treasury or the IRS. The potential exists for these types of events to result in future tax expense adjustments because of the difference in the federal corporate income tax rate between past and future periods and the effect of the tax rate change on ratemaking. In turn, these events also could potentially affect the regulatory liability for income taxes.

Coronavirus Aid, Relief, and Economic Security Act

In response to the economic impacts of the COVID-19 pandemic, President Trump signed the Coronavirus Aid, Relief, and Economic Security Act (CARES Act) into law on March 27, 2020. The CARES Act provisions that result in the most significant opportunities for tax relief to Entergy and the Registrant Subsidiaries are (i) permitting a five-year carryback of 2018-2020 NOLs, (ii) removing the 80 percent limitation on NOLs carried to tax years beginning before 2021, (iii) increasing the limitation on interest expense deductibility for 2019 and 2020, (iv) accelerating available refunds for minimum tax credit carryforwards, modifying limitations on charitable contributions during 2020, and (v) delaying the payment of employer payroll taxes. Entergy deferred approximately $64 million of 2020 payroll tax payments, payable in equal installments over two years. The initial installment of $32 million was paid in December 2021. The second installment will be paid in December 2022.

Tax Accounting Methods

In 2018, Entergy Arkansas and Entergy Mississippi accrued deductible temporary differences related to mark-to-market tax accounting for wholesale electric contracts of $2.1 billion and $1.9 billion, respectively.

Consolidated Income Tax Return of Entergy Corporation

In September 2019, Entergy Utility Holding Company, LLC and its regulated, wholly-owned subsidiaries including Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans, became eligible to and joined the Entergy Corporation consolidated federal income tax group. As a result of these four Utility operating companies re-joining the Entergy Corporation consolidated tax return group, Entergy was able to recognize a $41 million deferred tax asset associated with a previously unrecognized net operating loss carryover.

Stock Compensation

In accordance with stock compensation accounting rules, Entergy and the Registrant Subsidiaries recognized excess tax deductions as a reduction of income tax expense in the first quarter 2020. Due to the vesting and exercise of certain Entergy stock-based awards, Entergy recorded a permanent tax reduction of approximately $24.7 million, including $4.8 million for Entergy Arkansas, $8.6 million for Entergy Louisiana, $2.7 million for Entergy Mississippi, $1.5 million for Entergy New Orleans, $2.7 million for Entergy Texas, and $1.3 million for System Energy.

NOTE 4. REVOLVING CREDIT FACILITIES, LINES OF CREDIT, AND SHORT-TERM BORROWINGS

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2021 as follows:


Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of December 31, 2021	Letters of Credit Outstanding as of December 31, 2021
Entergy Arkansas	April 2022	$25 million (b)	2.75%	—	—
Entergy Arkansas	June 2026	$150 million (c)	1.23%	—	—
Entergy Louisiana	June 2026	$350 million (c)	1.32%	$125 million	—
Entergy Mississippi	April 2022	$10 million (d)	1.60%	—	—
Entergy Mississippi	April 2022	$35 million (d)	1.60%	—	—
Entergy Mississippi	April 2022	$37.5 million (d)	1.60%	—	—
Entergy New Orleans	June 2024	$25 million (c)	1.73%	—	—
Entergy Texas	June 2026	$150 million (c)	1.60%	—	$1.3 million

a.The interest rate is the estimated interest rate as of December 31, 2021 that would have been applied to outstanding borrowings under the facility.

b.Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.

c.The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas.

d.Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.

The commitment fees on the credit facilities range from 0.075% to 0.375% of the undrawn commitment amount for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas, and of the entire facility amount for Entergy New Orleans. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant.

In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2021:

Company

Amount of Uncommitted Facility

Letter of Credit Fee

Letters of Credit Issued as of December 31, 2021 (a) (b)

Entergy Arkansas

$25 million

0.78%

$8.5 million

Entergy Louisiana

$125 million

0.78%

$15.0 million

Entergy Mississippi

$65 million

0.78%

$9.3 million

Entergy New Orleans

$15 million

1.00%

$1.0 million

Entergy Texas

$80 million

0.875%

$79.6 million

(a) As of December 31, 2021, letters of credit posted with MISO covered financial transmission right exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights.

(b) As of December 31, 2021, in addition to the $9.3 million MISO letter of credit, Entergy Mississippi has $1 million of non-MISO letters of credit outstanding under this facility.

The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. The current FERC-authorized short-term borrowing limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through October 2023. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements. The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:


	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$140
Entergy Louisiana	$450	$—
Entergy Mississippi	$175	$—
Entergy New Orleans	$150	$—
Entergy Texas	$200	$80
System Energy	$200	$—

NOTE 5. LONG - TERM DEBT

Details of long-term debt are presented on FERC Form 1 pages 256-257. Entergy Mississippi has obtained long-term financing authorizations from the FERC that extend through October 2023.

NOTE 6. PREFERRED EQUITY AND NONCONTROLLING INTEREST

Note 6 to the financial statements is not applicable for Entergy Mississippi.

NOTE 7. COMMON EQUITY

Note 7 to the financial statement is not applicable for Entergy Mississippi.

NOTE 8. COMMITMENTS AND CONTINGENCIES

Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition. Entergy discusses regulatory proceedings in Note 2 to the financial statements and discusses tax proceedings in Note 3 to the financial statements.

Property Insurance

Entergy’s nuclear owner/licensee subsidiaries are members of NEIL, a mutual insurance company that provides property damage coverage, including decontamination and reactor stabilization, to the members’ nuclear generating plants. The property damage insurance limits procured by Entergy for its Utility plants and Entergy Wholesale Commodity plants are in compliance with the financial protection requirements of the NRC.

Under the property damage and accidental outage insurance programs, all NEIL insured plants could be subject to assessments should losses exceed the accumulated funds available from NEIL. Effective April 1, 2021, the maximum amounts of such possible assessments per occurrence were as follows:


			Assessments
			(In Millions)
Utility:
Entergy Arkansas			$27.6
Entergy Louisiana			$49.2
Entergy Mississippi			$0.11
Entergy New Orleans			$0.11
Entergy Texas			N/A
System Energy			$21.4

In the event that one or more acts of terrorism causes property damage under one or more or all nuclear insurance policies issued by NEIL (including, but not limited to, those described above) within 12 months from the date the first property damage occurs, the maximum recovery under all such nuclear insurance policies shall be an aggregate not exceeding $3.24 billion plus the additional amounts recovered for such losses from reinsurance, indemnity, and any other sources applicable to such losses.

Non-Nuclear Property Insurance

Entergy’s non-nuclear property insurance program provides coverage on a system-wide basis for Entergy’s non-nuclear assets. The insurance program provides coverage for property damage up to $400 million per occurrence in excess of a $20 million self-insured retention except for property damage caused by the following: earthquake shock, flood, and named windstorm, including associated storm surge. For earthquake shock and flood, the insurance program provides coverage up to $400 million on an annual aggregate basis in excess of a $40 million self-insured retention. For named windstorm and associated storm surge, the insurance program provides coverage up to $125 million on an annual aggregate basis in excess of a $40 million self-insured retention. The coverage provided by the insurance program for the Entergy New Orleans gas distribution system is limited to $50 million per occurrence and is subject to the same annual aggregate limits and retentions listed above for earthquake shock, flood, and named windstorm, including associated storm surge.

Covered property generally includes power plants, substations, facilities, inventories, and gas distribution-related properties. Excluded property generally includes transmission and distribution lines, poles, and towers. For substations valued at $5 million or less, coverage for named windstorm and associated storm surge is excluded. This coverage is in place for Entergy Corporation, the Registrant Subsidiaries, and certain other Entergy subsidiaries. Entergy also purchases $400 million in terrorism insurance coverage for its conventional property. The Terrorism Risk Insurance Reauthorization Act of 2007 created a government program that provides for up to $100 billion in coverage in excess of existing coverage for a terrorist event. Under current law, the Terrorism Risk Insurance Act extends through 2027.

Employment and Labor-related Proceedings

The Registrant Subsidiaries and other Entergy subsidiaries and related entities are responding to various lawsuits in both state and federal courts and to other labor-related proceedings filed by current and former employees, recognized bargaining representatives, and certain third parties. Generally, the amount of damages being sought is not specified in these proceedings. These actions may include, but are not limited to, allegations of wrongful employment actions; wage disputes and other claims under the Fair Labor Standards Act or its state counterparts; claims of race, gender, age, and disability discrimination; disputes arising under collective bargaining agreements; unfair labor practice proceedings and other administrative proceedings before the National Labor Relations Board or concerning the National Labor Relations Act; claims of retaliation; claims of harassment and hostile work environment; and claims for or regarding benefits under various Entergy Corporation-sponsored plans. Entergy and the Registrant Subsidiaries and related entities are responding to these lawsuits and proceedings and deny liability to the claimants. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of Entergy or the Utility operating companies.

Grand Gulf - Related Agreements

Unit Power Sales Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy)

System Energy has agreed to sell all of its share of capacity and energy from Grand Gulf to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans in accordance with specified percentages (Entergy Arkansas-36%, Entergy Louisiana-14%, Entergy Mississippi-33%, and Entergy New Orleans-17%) as ordered by the FERC. Charges under this agreement are paid in consideration for the purchasing companies’ respective entitlement to receive capacity and energy and are payable irrespective of the quantity of energy delivered. The agreement will remain in effect until terminated by the parties and the termination is approved by the FERC, most likely upon Grand Gulf’s retirement from service. In December 2016 the NRC granted the extension of Grand Gulf’s operating license to 2044. Monthly obligations are based on actual capacity and energy costs. The average monthly payments for 2021 under the agreement were approximately $16.4 million for Entergy Arkansas, $6.5 million for Entergy Louisiana, $14.6 million for Entergy Mississippi, and $7.9 million for Entergy New Orleans. See Note 2 to the financial statements for discussion of the complaints filed with the FERC against System Energy seeking a reduction in the return on equity component of the Unit Power Sales Agreement and other complaints filed with the FERC regarding the rates charged by System Energy under the System Agreement.

Availability Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy)

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans are individually obligated to make payments or subordinated advances to System Energy in accordance with stated percentages (Entergy Arkansas-17.1%, Entergy Louisiana-26.9%, Entergy Mississippi-31.3%, and Entergy New Orleans-24.7%) in amounts that, when added to amounts received under the Unit Power Sales Agreement or otherwise, are adequate to cover all of System Energy’s operating expenses as defined, including an amount sufficient to amortize the cost of Grand Gulf 2 over 27 years (See Reallocation Agreement terms below) and expenses incurred in connection with a permanent shutdown of Grand Gulf. System Energy has assigned its rights to payments and advances to certain creditors as security for certain obligations. Since commercial operation of Grand Gulf began, payments under the Unit Power Sales Agreement have exceeded the amounts payable under the Availability Agreement. Accordingly, no payments under the Availability Agreement have ever been required. If Entergy Arkansas or Entergy Mississippi fails to make its Unit Power Sales Agreement

payments, and System Energy is unable to obtain funds from other sources, Entergy Louisiana and Entergy New Orleans could become subject to claims or demands by System Energy or its creditors for payments or advances under the Availability Agreement (or the assignments thereof) equal to the difference between their required Unit Power Sales Agreement payments and their required Availability Agreement payments.

Reallocation Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy)

System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans entered into the Reallocation Agreement relating to the sale of capacity and energy from Grand Gulf and the related costs, in which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans agreed to assume all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability Agreement. The FERC’s decision allocating a portion of Grand Gulf capacity and energy to Entergy Arkansas supersedes the Reallocation Agreement as it relates to Grand Gulf. Responsibility for any Grand Gulf 2 amortization amounts has been individually allocated (Entergy Louisiana-26.23%, Entergy Mississippi-43.97%, and Entergy New Orleans-29.80%) under the terms of the Reallocation Agreement. However, the Reallocation Agreement does not affect Entergy Arkansas’s obligation to System Energy’s lenders under the assignments referred to in the preceding paragraph. Entergy Arkansas would be liable for its share of such amounts if Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans were unable to meet their contractual obligations. No payments of any amortization amounts will be required so long as amounts paid to System Energy under the Unit Power Sales Agreement, including other funds available to System Energy, exceed amounts required under the Availability Agreement, which is expected to be the case for the foreseeable future.

NOTE 9. ASSET RETIREMENT OBLIGATIONS

Accounting standards require companies to record liabilities for all legal obligations associated with the retirement of long-lived assets that result from the normal operation of the assets. For Entergy, substantially all of its asset retirement obligations consist of its liability for decommissioning its nuclear power plants. In addition, an insignificant amount of removal costs associated with non-nuclear power plants is also included in the decommissioning and asset retirement costs line item on the balance sheets.

These liabilities are recorded at their fair values (which are the present values of the estimated future cash outflows) in the period in which they are incurred, with an accompanying addition to the recorded cost of the long-lived asset. The asset retirement obligation is accreted each year through a charge to expense, to reflect the time value of money for this present value obligation. The accretion will continue through the completion of the asset retirement activity. The amounts added to the carrying amounts of the long-lived assets will be depreciated over the useful lives of the assets. The application of accounting standards related to asset retirement obligations is earnings neutral to the rate-regulated business of the Registrant Subsidiaries.

The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2021 and 2020 by the Registrant Subsidiaries were as follows:


	Liabilities as of December 31, 2020	Accretion	Spending	Dispositions	Liabilities as of December 31, 2021
	(In Millions)

Utility
Entergy Arkansas	1,314.2	77.7	—	(1.5)	1,390.4
Entergy Louisiana	1,573.3	79.9	—	—	1,653.2


Entergy Mississippi	9.8	0.5	—	—	10.3
Entergy New Orleans	3.8	0.2	—	—	4.0
Entergy Texas	8.1	0.4	—	—	8.5
System Energy	968.9	38.7	—	—	1,007.6


	Liabilities as of December 31, 2019	Accretion	Spending	Liabilities as of December 31, 2020
	(In Millions)
Utility
Entergy Arkansas	1,242.6	73.3	(1.7)	1,314.2
Entergy Louisiana	1,497.3	76.0	—	1,573.3
Entergy Mississippi	9.7	0.6	(0.5)	9.8
Entergy New Orleans	3.5	0.3	—	3.8
Entergy Texas	7.6	0.5	—	8.1
System Energy	931.7	37.2	—	968.9

Coal Combustion Residuals

In June 2010 the EPA issued a proposed rule on coal combustion residuals (CCRs) that contained two primary regulatory options: (1) regulating CCRs destined for disposal in landfills or received (including stored) in surface impoundments as so-called “special wastes” under the hazardous waste program of Resource Conservation and Recovery Act (RCRA) Subtitle C; or (2) regulating CCRs destined for disposal in landfills or surface impoundments as non-hazardous wastes under Subtitle D of RCRA. Under both options, CCRs that are beneficially reused in certain processes would remain excluded from hazardous waste regulation. In April 2015 the EPA published the final CCR rule with the material being regulated under the second scenario presented above - as non-hazardous wastes regulated under RCRA Subtitle D. The final regulations create new compliance requirements including modified storage, new notification and reporting practices, product disposal considerations, and CCR unit closure criteria. Entergy believes that on-site disposal options will be available at its facilities, to the extent needed for CCR that cannot be transferred for beneficial reuse. In December 2016 the Water Infrastructure Improvements for the Nation Act (WIIN Act) was signed into law, which authorizes states to regulate coal ash rather than leaving primary enforcement to citizen suit actions. States may submit to the EPA proposals for permit programs.

NOTE 10. LEASES

As of December 31, 2021 and 2020, Entergy and the Registrant Subsidiaries held operating and finance leases for fleet vehicles used in operations, real estate, and aircraft. Excluded are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases under the accounting standards.

Leases have remaining terms of one year to 59 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications that would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor. Due to the nature of the agreements and

Entergy’s continuing relationship with the lessor, however, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly.

The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2021:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Operating lease cost	$15,087	$14,368	$7,018	$1,745	$5,370
Finance lease cost:
Amortization of right-of-use assets	$2,860	$3,938	$1,766	$731	$1,493
Interest on lease liabilities	$432	$607	$270	$124	$214

Of the lease costs disclosed above, Entergy Mississippi had $703 thousand in short-term lease costs for the year ended December 31, 2021.

The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities.

The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2020:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Operating lease cost	$14,344	$13,944	$6,584	$1,443	$4,870
Finance lease cost:
Amortization of right-of-use assets	$2,693	$4,097	$1,627	$712	$1,340
Interest on lease liabilities	$408	$597	$254	$120	$196

The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities.

Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below.

Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021 and 2020 are the following amounts:

Entergy Arkansas

Entergy Louisiana

Entergy Mississippi

Entergy New Orleans

Entergy Texas


	(In Thousands)
2021
Operating leases	$56,099	$46,443	$16,831	$5,480	$14,986
Finance leases	$15,043	$19,007	$9,114	$4,023	$7,583

2020
Operating leases	$55,840	$43,189	$16,538	$5,222	$14,738
Finance leases	$12,447	$16,425	$7,452	$3,428	$5,719

The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Current liabilities:
Operating leases	$12,695	$12,520	$5,866	$1,491	$4,489
Finance leases	$2,964	$4,001	$1,843	$812	$1,476
Non-current liabilities:
Operating leases	$43,420	$33,931	$10,976	$3,994	$10,505
Finance leases	$12,079	$15,006	$7,271	$3,211	$6,107

The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2020:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Current liabilities:
Operating leases	$11,942	$11,934	$5,738	$1,406	$4,277
Finance leases	$2,660	$3,821	$1,644	$686	$1,327
Non-current liabilities:
Operating leases	$43,914	$31,260	$10,867	$3,819	$10,469
Finance leases	$9,788	$12,603	$5,808	$2,741	$4,392

The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2021:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas

Weighted average remaining lease terms:
Operating leases	5.13	4.65	5.36	5.35	3.94


Finance leases	5.89	5.57	5.63	5.94	5.97
Weighted average discount rate:
Operating leases	3.10	2.93	3.00	2.99	3.04
Finance leases	2.80	3.08	2.87	3.03	2.79

The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2020:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas

Weighted average remaining lease terms:
Operating leases	5.74	4.72	5.30	5.78	4.30
Finance leases	5.60	5.20	5.44	5.69	5.39
Weighted average discount rate:
Operating leases	3.34	3.11	3.43	3.09	3.07
Finance leases	3.18	3.33	3.22	3.35	3.22

Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2021 are as follows:

Operating Leases


Year	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)

2022	$14,180	$13,706	$6,280	$1,682	$4,888
2023	12,713	11,791	4,181	1,441	4,449
2024	11,150	9,618	3,174	1,182	3,427
2025	9,292	6,694	2,168	773	1,933
2026	7,314	4,081	827	398	771
Years thereafter	5,892	3,574	1,924	601	423
Minimum lease payments	60,541	49,464	18,554	6,077	15,891
Less: amount representing interest	4,425	3,013	1,711	592	898
Present value of net minimum lease payments	$56,116	$46,451	$16,843	$5,485	$14,993

Finance Leases


Year	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)

2022	$3,319	$4,481	$2,054	$854	$1,637
2023	3,100	4,231	1,971	814	1,532
2024	2,791	3,671	1,783	712	1,382
2025	2,449	3,122	1,529	621	1,256
2026	2,018	2,367	1,202	545	1,016
Years thereafter	2,477	2,613	1,220	673	1,296
Minimum lease payments	16,154	20,485	9,759	4,219	8,119
Less: amount representing interest	1,111	1,478	645	196	536
Present value of net minimum lease payments	$15,043	$19,007	$9,114	$4,023	$7,583

In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations, fuel storage agreements, and purchased power agreements and to allocate the contract consideration to both lease and non-lease components for real estate leases.

NOTE 11. RETIREMENT, OTHER POSTRETIREMENT BENEFITS, AND DEFINED CONTRIBUTION PLANS

Qualified Pension Plans

Entergy has eight defined benefit qualified pension plans. The Entergy Corporation Retirement Plan for Non-Bargaining Employees (Non-Bargaining Plan I), the Entergy Corporation Retirement Plan for Bargaining Employees (Bargaining Plan I), the Entergy Corporation Retirement Plan II for Non-Bargaining Employees (Non-Bargaining Plan II), the Entergy Corporation Retirement Plan II for Bargaining Employees, the Entergy Corporation Retirement Plan III, and the Entergy Corporation Retirement Plan IV for Bargaining Employees are non-contributory final average pay plans that provide pension benefits based on employees’ credited service and compensation during employment. Non-bargaining employees whose most recent date of hire is after June 30, 2014 and before January 1, 2021 do not participate in a final average pay plan, but instead participate in the Entergy Corporation Cash Balance Plan for Non-Bargaining Employees (Non-Bargaining Cash Balance Plan). Effective January 1, 2021, the Non-Bargaining Cash Balance Plan was closed to non-bargaining employees whose most recent date of hire is after December 31, 2020, who instead may be eligible to participate in, and receive a discretionary employer contribution under, the Savings Plan of Entergy Corporation and Subsidiaries VIII, an Entergy-sponsored tax-qualified defined contribution plan that includes a 401(k) feature. Certain bargaining employees whose most recent date of hire is after June 30, 2014, or such later date provided for in their applicable collective bargaining agreements, participate in the Entergy Corporation Cash Balance Plan for Bargaining Employees (Bargaining Cash Balance Plan). Effective January 1, 2021, the Bargaining Cash Balance Plan was amended to close participation in the plan to those bargaining employees whose most recent hire date is after December 31, 2020 or such later date provided for in their applicable collective bargaining agreements. The Registrant Subsidiaries participate in these four plans: Non-Bargaining Plan I, Bargaining Plan I, Non-Bargaining Cash Balance Plan, and Bargaining Cash Balance Plan. Effective January 1, 2022, the Non-Bargaining Cash Balance Plan was merged with and into Non-Bargaining Plan I.

The assets of the six final average pay defined benefit qualified pension plans are held in a master trust established by Entergy, and the assets of the two cash balance pension plans are held in a second master trust established by Entergy. Each pension plan has an undivided beneficial interest in each of the investment accounts in its respective master trust that is maintained by a trustee. Use of the master trusts permits the commingling of the trust assets of the pension plans of Entergy Corporation and its Registrant Subsidiaries for investment and administrative purposes. Although assets in the master trusts are commingled, the trustee maintains supporting records for the purpose of allocating the trust level equity in net earnings (loss) and the administrative expenses of the investment accounts in each trust to the various participating pension plans in that particular trust. The fair value of the trusts’ assets is determined by the trustee and certain investment managers. For each trust, the trustee calculates a daily earnings factor, including realized and unrealized gains or losses, collected and accrued income, and administrative expenses, and allocates earnings to each plan in the master trusts on a pro rata basis. Effective January 1, 2022, the assets of the remaining cash balance pension plan held in a second master trust were merged with and into a master trust that holds the assets of the six final average pay defined benefit qualified pension plans.

Within each pension plan, the record of each Registrant Subsidiary’s beneficial interest in the plan assets is maintained by the plan’s actuary and is updated quarterly. Assets for each Registrant Subsidiary are increased for investment net income and contributions, and are decreased for benefit payments. A plan’s investment net income/loss (i.e. interest and dividends, realized and unrealized gains and losses and expenses) is allocated to the Registrant Subsidiaries participating in that plan based on the value of assets for each Registrant Subsidiary at the beginning of the quarter adjusted for contributions and benefit payments made during the quarter.

Entergy Corporation and its subsidiaries fund pension plans in an amount not less than the minimum required contribution under the Employee Retirement Income Security Act of 1974, as amended, and the Internal Revenue Code of 1986, as amended. The assets of the plans include common and preferred stocks, fixed-income securities, interest in a money market fund, and insurance contracts. The Registrant Subsidiaries’ pension costs are recovered from customers as a component of cost of service in each of their respective jurisdictions.

Components of Qualified Net Pension Cost and Other Amounts Recognized as a Regulatory Asset and/or Accumulated Other Comprehensive Income (AOCI)

The Registrant Subsidiaries’ total 2021, 2020, and 2019 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their employees included the following components:


2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Net periodic pension cost:
Service cost - benefits earned during the period	$28,632	$38,271	$9,070	$3,038	$6,921	$8,851
Interest cost on projected benefit obligation	35,683	39,740	10,446	4,392	8,381	9,087
Expected return on assets	(78,368)	(89,821)	(22,407)	(10,598)	(21,158)	(19,254)
Recognized net loss	69,290	67,015	20,007	7,596	12,676	18,404
Settlement charges	37,682	61,945	16,710	5,431	11,797	12,260
Net pension cost	$92,919	$117,150	$33,826	$9,859	$18,617	$29,348


Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Net gain	($96,066)	($89,534)	($29,675)	($16,159)	($18,217)	($27,617)
Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year:
Amortization of net loss	(69,290)	(67,015)	(20,007)	(7,596)	(12,676)	(18,404)
Settlement charge	(37,682)	(61,945)	(16,710)	(5,431)	(11,797)	(12,260)
Total	($203,038)	($218,494)	($66,392)	($29,186)	($42,690)	($58,281)
Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax)	($110,119)	($101,344)	($32,566)	($19,327)	($24,073)	($28,933)


2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Net periodic pension cost:
Service cost - benefits earned during the period	$26,329	$35,158	$8,060	$2,654	$6,116	$7,883
Interest cost on projected benefit obligation	44,165	50,432	12,922	5,825	10,731	11,006
Expected return on assets	(78,187)	(89,691)	(23,147)	(10,509)	(21,951)	(18,757)
Recognized net loss	68,338	66,640	18,983	8,018	13,173	17,104
Settlement charges	21,078	8,109	3,366	—	4,289	105
Net pension cost	$81,723	$70,648	$20,184	$5,988	$12,358	$17,341
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Net loss	$106,178	$90,064	$36,899	$8,148	$13,379	$35,403
Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year:
Amortization of net loss	(69,713)	(68,248)	(19,393)	(8,213)	(13,564)	(17,434)
Settlement charge	(21,078)	(8,109)	(3,366)	—	(4,289)	(105)
Total	$15,387	$13,707	$14,140	($65)	($4,474)	$17,864
Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax)	$97,110	$84,355	$34,324	$5,923	$7,884	$35,205

2019

Entergy Arkansas

Entergy Louisiana

Entergy Mississippi

Entergy New Orleans

Entergy Texas

System Energy


	(In Thousands)
Net periodic pension cost:
Service cost - benefits earned during the period	$21,043	$29,137	$6,516	$2,274	$5,401	$6,199
Interest cost on projected benefit obligation	56,701	63,529	16,272	7,495	14,451	13,456
Expected return on assets	(80,705)	(90,607)	(23,873)	(10,785)	(23,447)	(18,710)
Recognized net loss	47,361	46,571	12,416	6,117	9,335	11,400
Net pension cost	$44,400	$48,630	$11,331	$5,101	$5,740	$12,345
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Net loss	$118,898	$99,346	$41,088	$6,531	$10,869	$36,711
Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year:
Amortization of net loss	(47,361)	(46,571)	(12,416)	(6,117)	(9,335)	(11,400)
Total	$71,537	$52,775	$28,672	$414	$1,534	$25,311
Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax)	$115,937	$101,405	$40,003	$5,515	$7,274	$37,656

Qualified Pension Obligations, Plan Assets, Funded Status, Amounts Recognized in the Balance Sheet

Qualified pension obligations, plan assets, funded status, amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows:


2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Change in Projected Benefit Obligation (PBO)
Balance at January 1	$1,739,382	$1,927,271	$510,109	$220,287	$410,664	$441,148
Service cost	28,632	38,271	9,070	3,038	6,921	8,851
Interest cost	35,683	39,740	10,446	4,392	8,381	9,087
Actuarial gain	(41,227)	(28,439)	(14,831)	(9,118)	(3,971)	(14,746)
Benefits paid (a)	(183,124)	(240,447)	(65,936)	(23,219)	(50,193)	(49,546)
Balance at December 31	$1,579,346	$1,736,396	$448,858	$195,380	$371,802	$394,794
Change in Plan Assets
Fair value of assets at January 1	$1,285,856	$1,476,306	$371,394	$172,551	$349,748	$310,818
Actual return on plan assets	133,207	150,917	37,251	17,639	35,405	32,125
Employer contributions	66,649	59,882	13,715	5,395	6,955	18,663
Benefits paid (a)	(183,124)	(240,447)	(65,936)	(23,219)	(50,193)	(49,546)


Fair value of assets at December 31	$1,302,588	$1,446,658	$356,424	$172,366	$341,915	$312,060
Funded status	($276,758)	($289,738)	($92,434)	($23,014)	($29,887)	($82,734)
Amounts recognized in the balance sheet (funded status)
Non-current liabilities	($276,758)	($289,738)	($92,434)	($23,014)	($29,887)	($82,734)
Amounts recognized as regulatory asset
Net loss	$612,963	$556,345	$173,511	$62,805	$113,790	$153,782
Amounts recognized as AOCI (before tax)
Net loss	$—	$23,181	$—	$—	$—	$—

(a) Including settlement lump sum benefit payments of ($104.4) million at Entergy Arkansas, ($166.6) million at Entergy Louisiana, ($45.7) million at Entergy Mississippi, ($14.3) million at Entergy New Orleans, ($31.9) million at Entergy Texas, and ($33) million at System Energy.


2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Change in Projected Benefit Obligation (PBO)
Balance at January 1	$1,615,084	$1,784,474	$471,510	$206,962	$396,764	$393,607
Service cost	26,329	35,158	8,060	2,654	6,116	7,883
Interest cost	44,165	50,432	12,922	5,825	10,731	11,006
Actuarial loss	196,755	196,032	62,564	20,535	37,579	57,574
Benefits paid (a)	(142,951)	(138,825)	(44,947)	(15,689)	(40,526)	(28,922)
Balance at December 31	$1,739,382	$1,927,271	$510,109	$220,287	$410,664	$441,148
Change in Plan Assets
Fair value of assets at January 1	$1,200,035	$1,364,030	$354,928	$160,777	$339,126	$282,668
Actual return on plan assets	168,764	195,658	48,812	22,896	46,151	40,927
Employer contributions	60,008	55,443	12,601	4,567	4,997	16,145
Benefits paid (a)	(142,951)	(138,825)	(44,947)	(15,689)	(40,526)	(28,922)
Fair value of assets at December 31	$1,285,856	$1,476,306	$371,394	$172,551	$349,748	$310,818
Funded status	($453,526)	($450,965)	($138,715)	($47,736)	($60,916)	($130,330)
Amounts recognized in the balance sheet (funded status)
Non-current liabilities	($453,526)	($450,965)	($138,715)	($47,736)	($60,916)	($130,330)
Amounts recognized as regulatory asset
Net loss	$816,002	$766,099	$239,904	$91,991	$156,480	$212,062


Amounts recognized as AOCI (before tax)
Net loss	$—	$31,921	$—	$—	$—	$—

(a) Including settlement lump sum benefit payments of ($48.4) million at Entergy Arkansas, ($18.6) million at Entergy Louisiana, ($7.7) million at Entergy Mississippi, ($9.8) million at Entergy Texas, and ($236) thousand at System Energy.

The qualified pension plans incurred actuarial gains during 2021 primarily due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations and an actual return on assets exceeding the expected return on assets for 2021. The qualified pension plans incurred actuarial losses during 2020 primarily due to a fall in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. These losses were partially offset by gains resulting from the actual return on assets exceeding the expected return on assets for 2020.

Accumulated Pension Benefit Obligation

The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their employees as of December 31, 2021 and 2020 was as follows:


	December 31,
	2021	2020
	(In Thousands)
Entergy Arkansas	$1,463,966	$1,617,858
Entergy Louisiana	$1,574,273	$1,753,980
Entergy Mississippi	$407,851	$466,497
Entergy New Orleans	$178,010	$201,159
Entergy Texas	$342,441	$379,050
System Energy	$366,920	$410,296

Other Postretirement Benefits

Entergy also currently offers retiree medical, dental, vision, and life insurance benefits (other postretirement benefits) for eligible retired employees. Employees who commenced employment before July 1, 2014 and who satisfy certain eligibility requirements (including retiring from Entergy after a certain age and/or years of service with Entergy and immediately commencing their Entergy pension benefit), may become eligible for other postretirement benefits.

In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), will be eligible to participate in a new Entergy-sponsored retiree health plan, and will no longer be eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the new Entergy retiree health plan, Medicare-eligible participants will be eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. In accordance with accounting standards, the effects of this change are reflected in the December 31, 2020 other postretirement obligation. The changes affecting active bargaining unit employees will be negotiated with the unions prior to implementation, where necessary, and to the extent required by law.

Effective January 1, 1993, Entergy adopted an accounting standard requiring a change from a cash method to an accrual method of accounting for postretirement benefits other than pensions. Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have received regulatory approval to recover accrued other postretirement benefit costs through rates. The LPSC ordered Entergy Louisiana to continue the use of the pay-as-you-go method for ratemaking purposes for postretirement benefits other than pensions. However, the LPSC retains the flexibility to examine individual companies’ accounting for other postretirement benefits to determine if special exceptions to this order are warranted. Pursuant to regulatory directives, Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy contribute the other postretirement benefit costs collected in rates into external trusts. System Energy is funding, on behalf of Entergy Operations, other postretirement benefits associated with Grand Gulf.

Trust assets contributed by participating Registrant Subsidiaries are in master trusts, established by Entergy Corporation and maintained by a trustee. Each participating Registrant Subsidiary holds a beneficial interest in the trusts’ assets. The assets in the master trusts are commingled for investment and administrative purposes. Although assets are commingled, supporting records are maintained for the purpose of allocating the beneficial interest in net earnings/(losses) and the administrative expenses of the investment accounts to the various participating plans and participating Registrant Subsidiaries. Beneficial interest in an investment account’s net income/(loss) is comprised of interest and dividends, realized and unrealized gains and losses, and expenses. Beneficial interest from these investments is allocated to the plans and participating Registrant Subsidiary based on their portion of net assets in the pooled accounts.

Components of Net Other Postretirement Benefit Cost and Other Amounts Recognized as a Regulatory Asset and/or AOCI

Total 2021, 2020, and 2019 other postretirement benefit costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their employees included the following components:


2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy

Other postretirement costs:
Service cost - benefits earned during the period	$4,135	$6,174	$1,448	$437	$1,384	$1,340
Interest cost on APBO	3,726	4,520	1,110	521	1,269	878
Expected return on assets	(18,020)	—	(5,536)	(5,750)	(10,192)	(3,156)
Amortization of prior service credit	(1,121)	(4,920)	(1,775)	(916)	(3,742)	(436)
Recognized net (gain)/ loss	196	(364)	76	(712)	398	61
Net other postretirement benefit (income)/cost	($11,084)	$5,410	($4,677)	($6,420)	($10,883)	($1,313)
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Prior service cost/(credit) for the period	($85)	$357	$—	$—	($3,776)	$69
Net (gain)/loss	$9,956	($2,367)	($2,823)	($3,330)	$939	$210


Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year:
Amortization of prior service credit	1,121	4,920	1,775	916	3,742	436
Amortization of net (gain)/loss	(196)	364	(76)	712	(398)	(61)
Total	$10,796	$3,274	($1,124)	($1,702)	$507	$654
Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax)	($288)	$8,684	($5,801)	($8,122)	($10,376)	($659)


2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Other postretirement costs:
Service cost - benefits earned during the period	$3,626	$5,993	$1,468	$445	$1,219	$1,254
Interest cost on APBO	4,712	6,216	1,536	784	2,008	1,130
Expected return on assets	(17,104)	—	(5,167)	(5,382)	(9,643)	(2,958)
Amortization of prior service credit	(1,849)	(6,179)	(1,652)	(763)	(3,364)	(1,065)
Recognized net (gain)/loss	540	(447)	171	(13)	907	121
Net other postretirement benefit (income)/cost	($10,075)	$5,583	($3,644)	($4,929)	($8,873)	($1,518)
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Prior service cost/(credit) for the period	$12,320	($23,508)	($4,428)	($5,493)	($22,441)	($1,963)
Net (gain)/loss	$2,245	$8,744	($4,456)	($5,351)	($3,266)	$58
Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year:
Amortization of prior service credit	1,849	6,179	1,652	763	3,364	1,065
Amortization of net (gain)/ loss	(540)	447	(171)	13	(907)	(121)


Total	$15,874	($8,138)	($7,403)	($10,068)	($23,250)	($961)
Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax)	$5,799	($2,555)	($11,047)	($14,997)	($32,123)	($2,479)


2019	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Other postretirement costs:
Service cost - benefits earned during the period	$2,363	$4,639	$1,046	$367	$943	$973
Interest cost on APBO	7,226	10,664	2,681	1,581	3,415	1,902
Expected return on assets	(15,962)	—	(4,794)	(4,947)	(9,103)	(2,788)
Amortization of prior service credit	(4,950)	(7,349)	(1,756)	(682)	(2,243)	(1,450)
Recognized net (gain)/loss	576	(695)	723	231	485	354
Net other postretirement benefit (income)/cost	($10,747)	$7,259	($2,100)	($3,450)	($6,503)	($1,009)
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Net gain	(26,707)	(2,220)	(11,950)	(10,967)	(6,406)	(5,539)
Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year:
Amortization of prior service credit	4,950	7,349	1,756	682	2,243	1,450
Amortization of net (gain)/loss	(576)	695	(723)	(231)	(485)	(354)
Total	($22,333)	$5,824	($10,917)	($10,516)	($4,648)	($4,443)
Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax)	($33,080)	$13,083	($13,017)	($13,966)	($11,151)	($5,452)

Other Postretirement Benefit Obligations, Plan Assets, Funded Status, and Amounts Not Yet Recognized and Recognized in the Balance Sheet

Other postretirement benefit obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows:


2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Change in APBO
Balance at January 1	$209,369	$255,571	$61,990	$31,707	$74,233	$47,701
Service cost	4,135	6,174	1,448	437	1,384	1,340
Interest cost	3,726	4,520	1,110	521	1,269	878
Plan amendments	(85)	357	—	—	(3,776)	69
Plan participant contributions	5,637	5,186	1,386	403	1,491	1,353
Actuarial (gain)/loss	14,323	(2,367)	(1,335)	988	4,270	1,289
Benefits paid	(15,954)	(16,460)	(3,604)	(2,194)	(6,923)	(4,769)
Medicare Part D subsidy received	32	50	6	4	13	14
Balance at December 31	$221,183	$253,031	$61,001	$31,866	$71,961	$47,875
Change in Plan Assets
Fair value of assets at January 1	$304,192	$—	$93,475	$102,734	$174,096	$52,619
Actual return on plan assets	22,387	—	7,024	10,068	13,523	4,235
Employer contributions	(767)	11,274	(393)	126	98	1,212
Plan participant contributions	5,637	5,186	1,386	403	1,491	1,353
Benefits paid	(15,954)	(16,460)	(3,604)	(2,194)	(6,923)	(4,769)
Fair value of assets at December 31	$315,495	$—	$97,888	$111,137	$182,285	$54,650
Funded status	$94,312	($253,031)	$36,887	$79,271	$110,324	$6,775
Amounts recognized in the balance sheet
Current liabilities	$—	($15,839)	$—	$—	$—	$—
Non-current liabilities	94,312	(237,192)	36,887	79,271	110,324	6,775
Total funded status	$94,312	($253,031)	$36,887	$79,271	$110,324	$6,775
Amounts recognized in regulatory asset
Prior service cost/(credit)	$8,691	$—	($4,109)	($3,814)	($20,532)	($1,249)
Net (gain)/loss	(6,797)	—	(4,254)	(16,003)	2,571	2,967
	$1,894	$—	($8,363)	($19,817)	($17,961)	$1,718
Amounts recognized in AOCI (before tax)
Prior service credit	$—	($16,967)	$—	$—	$—	$—
Net gain	—	(17,551)	—	—	—	—
	$—	($34,518)	$—	$—	$—	$—


2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Change in APBO
Balance at January 1	$185,744	$274,175	$65,979	$38,460	$94,742	$47,348
Service cost	3,626	5,993	1,468	445	1,219	1,254
Interest cost	4,712	6,216	1,536	784	2,008	1,130
Plan amendments	12,320	(23,508)	(4,428)	(5,493)	(22,441)	(1,963)
Plan participant contributions	7,792	8,269	2,122	1,123	2,456	1,732
Actuarial (gain)/loss	18,257	8,744	684	(91)	5,952	3,025
Benefits paid	(23,141)	(24,395)	(5,382)	(3,530)	(9,721)	(4,851)
Medicare Part D subsidy received	59	77	11	9	18	26
Balance at December 31	$209,369	$255,571	$61,990	$31,707	$74,233	$47,701
Change in Plan Assets
Fair value of assets at January 1	$284,224	$—	$86,085	$93,858	$161,810	$48,471
Actual return on plan assets	33,116	—	10,307	10,642	18,861	5,925
Employer contributions	2,201	16,126	343	641	690	1,342
Plan participant contributions	7,792	8,269	2,122	1,123	2,456	1,732
Benefits paid	(23,141)	(24,395)	(5,382)	(3,530)	(9,721)	(4,851)
Fair value of assets at December 31	$304,192	$—	$93,475	$102,734	$174,096	$52,619
Funded status	$94,823	($255,571)	$31,485	$71,027	$99,863	$4,918
Amounts recognized in the balance sheet
Current liabilities	$—	($15,580)	$—	$—	$—	$—
Non-current liabilities	94,823	(239,991)	31,485	71,027	99,863	4,918
Total funded status	$94,823	($255,571)	$31,485	$71,027	$99,863	$4,918
Amounts recognized in regulatory asset
Prior service cost/(credit)	$7,655	$—	($5,884)	($4,730)	($20,498)	($1,754)
Net (gain)/loss	(16,557)	—	(1,355)	(13,385)	2,030	2,818
	($8,902)	$—	($7,239)	($18,115)	($18,468)	$1,064
Amounts recognized in AOCI (before tax)
Prior service credit	$—	($22,244)	$—	$—	$—	$—
Net gain	—	(15,548)	—	—	—	—
	$—	($37,792)	$—	$—	$—	$—

The other postretirement plans incurred actuarial losses during 2021 primarily due to a reduction in the projected Employer Group Waiver Plan (EGWP) revenue and updated census data. These losses were partially offset by gains resulting from the actual return on assets exceeding the expected return on assets for 2021 and a rise in bond

yields that resulted in increases to the discount rates used to develop the benefit obligations. The other postretirement plans incurred actuarial losses during 2020 primarily due to a reduction in the projected EGWP revenue and a fall in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. These losses were partially offset by gains resulting from the actual return on assets exceeding the expected return on assets for 2020, an update to the latest mortality projection scale MP-2020, and favorable claims experience.

Non-Qualified Pension Plans

Entergy also sponsors non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees.

The following Registrant Subsidiaries participate in Entergy’s non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. The net periodic pension cost for their employees for the non-qualified plans for 2021, 2020, and 2019, was as follows:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2021	$343	$307	$365	$30	$615
2020	$333	$148	$359	$31	$469
2019	$275	$159	$326	$20	$481

Included in the 2021 net periodic pension cost above are settlement charges of $155 thousand and $172 thousand for Entergy Louisiana and Entergy Texas, respectively, related to the lump sum benefits paid out of the plan. Included in the 2019 net periodic pension cost above are settlement charges of $40 thousand for Entergy Mississippi related to the lump sum benefits paid out of the plan. In 2020 there were no settlement charges related to the payment of lump sum benefits out of the plan.

The projected benefit obligation for their employees for the non-qualified plans as of December 31, 2021 and 2020 was as follows:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2021	$2,875	$1,469	$3,708	$1,069	$7,462
2020	$3,197	$1,965	$3,852	$247	$8,475

The accumulated benefit obligation for their employees for the non-qualified plans as of December 31, 2021 and 2020 was as follows:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2021	$2,482	$1,445	$3,377	$738	$7,355
2020	$2,626	$1,802	$3,345	$240	$7,949

The following amounts were recorded on the balance sheet as of December 31, 2021 and 2020:


2021	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Current liabilities	($248)	($186)	($190)	($31)	($3,080)
Non-current liabilities	(2,627)	(1,283)	(3,518)	(1,039)	(4,382)
Total funded status	($2,875)	($1,469)	($3,708)	($1,070)	($7,462)
Regulatory asset/(liability)	$1,059	$233	$1,368	$251	($706)
Accumulated other comprehensive income (before taxes)	$—	$10	$—	$—	$—


2020	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Current liabilities	($218)	($193)	($181)	($17)	($633)
Non-current liabilities	(2,979)	(1,772)	(3,671)	(230)	(7,842)
Total funded status	($3,197)	($1,965)	($3,852)	($247)	($8,475)
Regulatory asset/(liability)	$1,535	$424	$1,757	($558)	$147
Accumulated other comprehensive income (before taxes)	$—	$18	$—	$—	$—

The non-qualified pension plans incurred actuarial losses during 2021 primarily due to differences in recent retirement and lump sum experience relative to actuarial assumptions. The non-qualified pension plans incurred actuarial losses during 2020 primarily due to a fall in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations.

Accounting for Pension and Other Postretirement Benefits

Accounting standards require an employer to recognize in its balance sheet the funded status of its benefit plans. This is measured as the difference between plan assets at fair value and the benefit obligation. Entergy uses a December 31 measurement date for its pension and other postretirement plans. Employers are to record previously unrecognized gains and losses, prior service costs, and any remaining transition asset or obligation (that resulted from adopting prior pension and other postretirement benefits accounting standards) as comprehensive income and/or as a regulatory asset reflective of the recovery mechanism for pension and other postretirement benefit costs in the Registrant Subsidiaries’ respective regulatory jurisdictions. For the portion of Entergy Louisiana that is not regulated, the unrecognized prior service cost, gains and losses, and transition asset/obligation for its pension and other postretirement benefit obligations are recorded as other comprehensive income. Entergy Louisiana recovers other postretirement benefit costs on a pay-as-you-go basis and records the unrecognized prior service cost, gains and losses, and transition obligation for its other postretirement benefit obligation as other comprehensive income. Accounting standards also require that changes in the funded status be recorded as other comprehensive income and/or a regulatory asset in the period in which the changes occur.

With regard to pension and other postretirement costs, Entergy calculates the expected return on pension and other postretirement benefit plan assets by multiplying the long-term expected rate of return on assets by the market-related value (MRV) of plan assets. In general, Entergy determines the MRV of its pension plan assets by calculating a value that uses a 20-quarter phase-in of the difference between actual and expected returns and for its other postretirement benefit plan assets Entergy generally uses fair value.

In accordance with ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost”, the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income.

Qualified Pension Settlement Cost

Year-to-date lump sum benefit payments from the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining Employees exceeded the sum of the Plans’ 2021 service and interest cost, resulting in settlement costs. In accordance with accounting standards, settlement accounting requires immediate recognition of the portion of previously unrecognized losses associated with the settled portion of the plans’ pension liability. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy participate in one or both of the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining employees and incurred settlement costs. Similar to other pension costs, the settlement costs were included with employee labor costs and charged to expense and capital in the same manner that labor costs were charged. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans received regulatory approval to defer the expense portion of the settlement costs, with future amortization of the deferred settlement expense over the period in which the expense otherwise would be recorded had the immediate recognition not occurred.

Qualified Pension and Other Postretirement Plans’ Assets

The Plan Administrator’s trust asset investment strategy is to invest the assets in a manner whereby long-term earnings on the assets (plus cash contributions) provide adequate funding for retiree benefit payments. The mix of assets is based on an optimization study that identifies asset allocation targets in order to achieve the maximum return for an acceptable level of risk, while minimizing the expected contributions and pension and postretirement expense.

In the optimization studies, the Plan Administrator formulates assumptions about characteristics, such as expected asset class investment returns, volatility (risk), and correlation coefficients among the various asset classes. The future market assumptions used in the optimization study are determined by examining historical market characteristics of the various asset classes and making adjustments to reflect future conditions expected to prevail over the study period.

The target asset allocation for pension adjusts dynamically based on the pension plans’ funded status. The current targets are shown below. The expectation is that the allocation to fixed income securities will increase as the pension plans’ funded status increases. The following ranges were established to produce an acceptable, economically efficient plan to manage around the targets.

For postretirement assets the target and range asset allocations (as shown below) reflect recommendations made in the latest optimization study. The target asset allocations for postretirement assets adjust dynamically based on the funded status of each sub-account within each trust. The current weighted average targets shown below represent the aggregate of all targets for all sub-accounts within all trusts.

Entergy’s qualified pension and postretirement weighted-average asset allocations by asset category at December 31, 2021 and 2020 and the target asset allocation and ranges for 2021 are as follows:


Pension Asset Allocation	Target	Range			Actual 2021	Actual 2020
Domestic Equity Securities	39%	32%	to	46%	40%	38%
International Equity Securities	19%	15%	to	23%	20%	19%
Fixed Income Securities	42%	39%	to	45%	40%	42%
Other	0%	0%	to	10%	0%	1%


Postretirement Asset Allocation	Non-Taxable and Taxable
	Target	Range			Actual 2021	Actual 2020
Domestic Equity Securities	25%	20%	to	30%	28%	29%
International Equity Securities	17%	12%	to	22%	17%	18%
Fixed Income Securities	58%	53%	to	63%	55%	53%
Other	0%	0%	to	5%	0%	0%

In determining its expected long-term rate of return on plan assets used in the calculation of benefit plan costs, Entergy reviews past performance, current and expected future asset allocations, and capital market assumptions of its investment consultant and some investment managers.

The expected long-term rate of return for the qualified pension plans’ assets is based primarily on the geometric average of the historical annual performance of a representative portfolio weighted by the target asset allocation defined in the table above, along with other indications of expected return on assets. The time period reflected is a long-dated period spanning several decades.

The expected long-term rate of return for the non-taxable postretirement trust assets is determined using the same methodology described above for pension assets, but the aggregate asset allocation specific to the non-taxable postretirement assets is used.

For the taxable postretirement trust assets, the investment allocation includes tax-exempt fixed income securities. This asset allocation, in combination with the same methodology employed to determine the expected return for other postretirement assets (as described above), and with a modification to reflect applicable taxes, is used to produce the expected long-term rate of return for taxable postretirement trust assets.

Concentrations of Credit Risk

Entergy’s investment guidelines mandate the avoidance of risk concentrations. Types of concentrations specified to be avoided include, but are not limited to, investment concentrations in a single entity, type of industry, foreign country, geographic area and individual security issuance. As of December 31, 2021, all investment managers and assets were materially in compliance with the approved investment guidelines, therefore there were no significant concentrations (defined as greater than 10 percent of plan assets) of credit risk in Entergy’s pension and other postretirement benefit plan assets.

Fair Value Measurements

Accounting standards provide the framework for measuring fair value. That framework provides a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives

the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurements) and the lowest priority to unobservable inputs (Level 3 measurements).

The three levels of the fair value hierarchy are described below:

•Level 1 - Level 1 inputs are unadjusted quoted prices for identical assets or liabilities in active markets that the Plan has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.

•Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by an independent party that uses inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden if it is believed such would be more reflective of fair value. Level 2 inputs include the following:

- quoted prices for similar assets or liabilities in active markets;

- quoted prices for identical assets or liabilities in inactive markets;

- inputs other than quoted prices that are observable for the asset or liability; or

- inputs that are derived principally from or corroborated by observable market data by correlation or other means.

If an asset or liability has a specified (contractual) term, the Level 2 input must be observable for substantially the full term of the asset or liability.

•Level 3 - Level 3 refers to securities valued based on significant unobservable inputs.

Assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The following tables set forth by level within the fair value hierarchy, measured at fair value on a recurring basis at December 31, 2021, and December 31, 2020, a summary of the investments held in the master trusts for Entergy’s qualified pension and other postretirement plans in which the Registrant Subsidiaries participate.

Qualified Defined Benefit Pension Plan Trusts


2021	Level 1		Level 2		Level 3	Total
	(In Thousands)
Equity securities:
Corporate stocks:
Preferred	$16,231	(b)	$—		$—	$16,231
Common	1,001,169	(b)	—		—	1,001,169
Common collective trusts (c)						3,123,111
Fixed income securities:
U.S. Government securities	—		627,148	(a)	—	627,148
Corporate debt instruments	—		966,616	(a)	—	966,616


Registered investment companies (e)	92,347	(d)	3,004	(d)	—	1,129,070
Other	—		68,886	(f)	—	68,886
Other:
Insurance company general account (unallocated contracts)	—		5,961	(g)	—	5,961
Total investments	$1,109,747		$1,671,615		$—	$6,938,192
Cash						123,153
Other pending transactions						11,125
Less: Other postretirement assets included in total investments						(79,360)
Total fair value of qualified pension assets						$6,993,110


2020	Level 1		Level 2		Level 3	Total
	(In Thousands)
Equity securities:
Corporate stocks:
Preferred	$15,756	(b)	$—		$—	$15,756
Common	1,031,213	(b)	—		—	1,031,213
Common collective trusts (c)						2,958,767
Fixed income securities:
U.S. Government securities	—		731,319	(a)	—	731,319
Corporate debt instruments	—		1,029,370	(a)	—	1,029,370
Registered investment companies (e)	81,800	(d)	3,076	(d)	—	1,128,107
Other	156	(f)	56,323	(f)	—	56,479
Other:
Insurance company general account (unallocated contracts)	—		6,253	(g)	—	6,253
Total investments	$1,128,925		$1,826,341		$—	$6,957,264
Cash						2,316
Other pending transactions						(29,121)
Less: Other postretirement assets included in total investments						(76,033)
Total fair value of qualified pension assets						$6,854,426

Other Postretirement Trusts


2021	Level 1		Level 2		Level 3	Total
	(In Thousands)
Equity securities:
Common collective trust (c)						$312,594
Fixed income securities:
U.S. Government securities	62,240	(b)	89,951	(a)	—	152,191
Corporate debt instruments	—		152,562	(a)	—	152,562
Registered investment companies	28,450	(d)	—		—	28,450


Other	—	72,059	(f)	—	72,059
Total investments	$90,690	$314,572		$—	$717,856
Other pending transactions					(25,897)
Plus: Other postretirement assets included in the investments of the qualified pension trust					79,360
Total fair value of other postretirement assets					$771,319


2020	Level 1		Level 2		Level 3	Total
	(In Thousands)
Equity securities:
Common collective trust (c)						$315,191
Fixed income securities:
U.S. Government securities	46,498	(b)	97,604	(a)	—	144,102
Corporate debt instruments	—		147,287	(a)	—	147,287
Registered investment companies	16,965	(d)	—		—	16,965
Other	—		60,219	(f)	—	60,219
Total investments	$63,463		$305,110		$—	$683,764
Other pending transactions						(21,931)
Plus: Other postretirement assets included in the investments of the qualified pension trust						76,033
Total fair value of other postretirement assets						$737,866

a.Certain fixed income debt securities (corporate, government, and securitized) are stated at fair value as determined by broker quotes.

b.Common stocks, certain preferred stocks, and certain fixed income debt securities (government) are stated at fair value determined by quoted market prices.

c.The common collective trusts hold investments in accordance with stated objectives. The investment strategy of the trusts is to capture the growth potential of equity markets by replicating the performance of a specified index. Net asset value per share of common collective trusts estimate fair value. Common collective trusts are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table, but are included in the total.

d.Registered investment companies are money market mutual funds with a stable net asset value of one dollar per share. Registered investment companies may hold investments in domestic and international bond markets or domestic equities and estimate fair value using net asset value per share.

e.Certain of these registered investment companies are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table, but are included in the total.

f.The other remaining assets are U.S. municipal and foreign government bonds stated at fair value as determined by broker quotes and quoted market values.

g.The unallocated insurance contract investments are recorded at contract value, which approximates fair value. The contract value represents contributions made under the contract, plus interest, less funds used to pay benefits and contract expenses, and less distributions to the master trust.

Estimated Future Benefit Payments

Based upon the same assumptions, Entergy expects that benefits to be paid and the Medicare Part D subsidies to be received over the next ten years for the Registrant Subsidiaries for their employees will be as follows:


Estimated Future Qualified Pension Benefits Payments	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Year(s)
2022	$107,542	$120,365	$33,459	$13,992	$31,134	$26,953
2023	$104,328	$118,289	$33,055	$13,677	$30,381	$25,985
2024	$104,606	$117,416	$32,711	$13,333	$28,661	$26,155
2025	$102,411	$116,610	$31,838	$13,146	$26,807	$25,203
2026	$101,144	$114,232	$31,708	$12,875	$26,983	$24,939
2027 - 2031	$487,637	$534,665	$143,052	$58,299	$114,747	$123,220


Estimated Future Non-Qualified Pension Benefits Payments	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Year(s)
2022	$248	$186	$190	$31	$3,080
2023	$383	$172	$422	$82	$441
2024	$324	$159	$504	$104	$420
2025	$689	$146	$486	$135	$398
2026	$143	$133	$412	$128	$428
2027 - 2031	$878	$503	$1,927	$782	$1,677


Estimated Future Other Postretirement Benefits Payments (before Medicare Part D Subsidy)	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Year(s)
2022	$14,228	$15,845	$3,488	$2,449	$5,061	$2,828
2023	$13,652	$15,766	$3,550	$2,378	$4,998	$2,774
2024	$13,392	$15,404	$3,597	$2,288	$4,824	$2,668
2025	$13,021	$15,182	$3,657	$2,200	$4,686	$2,617
2026	$12,717	$14,868	$3,645	$2,096	$4,458	$2,511
2027 - 2031	$61,153	$70,094	$18,095	$9,058	$20,932	$12,474

Estimated Future Medicare Part D Subsidy

Entergy Arkansas

Entergy Louisiana

Entergy Mississippi

Entergy New Orleans

Entergy Texas

System Energy


	(In Thousands)
Year(s)
2022	$35	$6	$14	$—	$—	$1
2023	$3	$5	$15	$—	$—	$1
2024	$4	$7	$16	$—	$—	$1
2025	$4	$8	$17	$—	$—	$—
2026	$5	$7	$18	$1	$—	$1
2027 - 2031	$27	$51	$104	$—	$—	$4

Contributions

The Registrant Subsidiaries expect to contribute approximately the following to the qualified pension and other postretirement plans for their employees in 2022:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Pension Contributions	$40,840	$22,917	$12,852	$922	$1,924	$12,760
Other Postretirement Contributions	$517	$15,845	$130	$175	$66	$22

Actuarial Assumptions

The significant actuarial assumptions used in determining the pension PBO and the other postretirement benefit APBO as of December 31, 2021 and 2020 were as follows:


	2021	2020
Weighted-average discount rate:
Qualified pension	2.99% - 3.08% Blended 3.05%	2.60% - 2.83% Blended 2.77%
Other postretirement	2.94%	2.62%
Non-qualified pension	2.11%	1.61%
Weighted-average rate of increase in future compensation levels	3.98% - 4.40%	3.98% - 4.40%
Interest crediting rate	2.60%	2.60%
Assumed health care trend rate:
Pre-65	5.65%	5.87%
Post-65	5.90%	6.31%
Ultimate rate	4.75%	4.75%
Year ultimate rate is reached and beyond:
Pre-65	2032	2030
Post-65	2032	2028

The significant actuarial assumptions used in determining the net periodic pension and other postretirement benefit costs for 2021, 2020, and 2019 were as follows:


	2021	2020	2019
Weighted-average discount rate:
Qualified pension:
Service cost	2.81%	3.42%	4.57%


Interest cost	2.08%	2.99%	4.15%
Other postretirement:
Service cost	2.98%	3.27%	4.62%
Interest cost	1.86%	2.41%	4.01%
Non-qualified pension:
Service cost	1.48%	2.71%	3.94%
Interest cost	2.14%	2.25%	3.46%
Weighted-average rate of increase in future compensation levels	3.98% - 4.40%	3.98% - 4.40%	3.98%
Expected long-term rate of return on plan assets:
Pension assets	6.75%	7.00%	7.25%
Other postretirement non-taxable assets	6.00% - 6.75%	6.25% - 7.25%	6.50% - 7.50%
Other postretirement taxable assets	5.00%	5.25%	5.50%
Assumed health care trend rate:
Pre-65	5.87%	6.13%	6.59%
Post-65	6.31%	6.25%	7.15%
Ultimate rate	4.75%	4.75%	4.75%
Year ultimate rate is reached and beyond:
Pre-65	2030	2027	2027
Post-65	2028	2027	2026

With respect to the mortality assumptions, Entergy used the Pri-2012 Employee and Healthy Annuitant Tables with a fully generational MP-2020 projection scale, in determining its December 31, 2021 and 2020 pension plans’ PBOs and the Pri.H 2012 (headcount weighted) Employee and Healthy Annuitant Tables with a fully generational MP-2020 projection scale, in determining its December 31, 2021 and 2020 other postretirement benefit APBO.

Defined Contribution Plans

Entergy sponsors the Savings Plan of Entergy Corporation and Subsidiaries (System Savings Plan). The System Savings Plan is a defined contribution plan covering eligible employees of Entergy and certain of its subsidiaries. The participating Entergy subsidiary makes matching contributions to the System Savings Plan for all eligible participating employees in an amount equal to either 70% or 100% of the participants’ basic contributions, up to 6% of their eligible earnings per pay period. The matching contribution is allocated to investments as directed by the employee.

Entergy also sponsors the Savings Plan of Entergy Corporation and Subsidiaries VI (established in April 2007) and the Savings Plan of Entergy Corporation and Subsidiaries VII (established in April 2007) to which matching contributions are also made. The plans are defined contribution plans that cover eligible employees, as defined by each plan, of Entergy and certain of its subsidiaries.

Entergy also sponsors the Savings Plan of Entergy Corporation and Subsidiaries VIII (established January 2021) and the Savings Plan of Entergy Corporation and Subsidiaries IX (established January 2021) to which company contributions are made. The participating Entergy subsidiary makes matching contributions to these defined contribution plans for all eligible participating employees in an amount equal to 100% of the participants’

basic contributions, up to 5% of their eligible earnings per pay period. Eligible participants may also receive a discretionary annual company contribution up to 4% of the participant’s eligible earnings (subject to vesting).

The Registrant Subsidiaries’ 2021, 2020, and 2019 contributions to defined contribution plans for their employees were as follows:


Year	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2021	$4,820	$6,678	$3,045	$1,140	$2,699
2020	$4,515	$6,518	$2,863	$1,115	$2,596
2019	$4,111	$5,641	$2,424	$882	$2,136

NOTE 12. STOCK-BASED COMPENSATION

Note 12 to the financial statements is not applicable to the Registrant Subsidiaries.

NOTE 13. BUSINESS SEGMENT INFORMATION

Registrant Subsidiaries

Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.

NOTE 14. ACQUISITIONS

Note 14 to the financial statements is not applicable to Entergy Mississippi.

NOTE 15. RISK MANAGEMENT AND FAIR VALUES

Market Risk

In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk.

The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers.

Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current

market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives.

Derivatives

Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments.

Entergy used standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitated the netting of cash flows associated with a single counterparty and may have included collateral requirements. Cash, letters of credit, and parental/affiliate guarantees were obtained as security from counterparties in order to mitigate credit risk. The collateral agreements required a counterparty to post cash or letters of credit in the event an exposure exceeded an established threshold. The threshold represented an unsecured credit limit, which may have been supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allowed for termination and liquidation of all positions in the event of a failure or inability to post collateral.

Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of December 31, 2021 is 2.25 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of December 31, 2021 is 10 months for Entergy Mississippi and 3 months for Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of December 31, 2021 is 33,083,500 MMBtu for Entergy, including 16,420,000 MMBtu for Entergy Louisiana, 16,017,800 MMBtu for Entergy Mississippi, and 645,700 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral.

During the second quarter 2021, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2021 through May 31, 2022. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records

financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of December 31, 2021 is 57,836 GWh for Entergy, including 12,561 GWh for Entergy Arkansas, 25,973 GWh for Entergy Louisiana, 6,429 GWh for Entergy Mississippi, 2,643 GWh for Entergy New Orleans, and 10,003 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi and Entergy Texas as of December 31, 2021 and for Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2020.

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2021 and 2020 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.


Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant
		(In Millions)
2021
Assets:
Natural gas swaps and options	Prepayments and other	$5.7	$—	$5.7	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$5.3	$—	$5.3	Entergy Louisiana

Financial transmission rights	Prepayments and other	$2.3	$—	$2.3	Entergy Arkansas
Financial transmission rights	Prepayments and other	$0.6	$—	$0.6	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.3	$—	$0.3	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.1	$—	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$0.8	$—	$0.8	Entergy Texas

Liabilities:
Natural gas swaps	Other current liabilities	$6.7	$—	$6.7	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.5	$—	$0.5	Entergy New Orleans

Instrument

Balance Sheet Location

Gross Fair Value (a)

Offsetting Position (b)

Net Fair Value (c) (d)

Registrant



2020
Assets:
Natural gas swaps and options	Prepayments and other	$0.8	$—	$0.8	Entergy Louisiana
Natural gas swaps and options	Other deferred debits and other assets	$0.5	$—	$0.5	Entergy Louisiana

Financial transmission rights	Prepayments and other	$2.9	($0.2)	$2.7	Entergy Arkansas
Financial transmission rights	Prepayments and other	$4.3	($0.1)	$4.2	Entergy Louisiana
Financial transmission rights	Prepayments and other	$0.6	$—	$0.6	Entergy Mississippi
Financial transmission rights	Prepayments and other	$0.2	($0.1)	$0.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$1.6	$—	$1.6	Entergy Texas

Liabilities:
Natural gas swaps and options	Other current liabilities	$0.3	$—	$0.3	Entergy Louisiana
Natural gas swaps and options	Other non-current liabilities	$1.3	$—	$1.3	Entergy Louisiana
Natural gas swaps	Other current liabilities	$5.0	$—	$5.0	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.3	$—	$0.3	Entergy New Orleans

a.Represents the gross amounts of recognized assets/liabilities

b.Represents the netting of fair value balances with the same counterparty

c.Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets

d.As of December 31, 2021 letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas. As of December 31, 2020, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Louisiana, $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $0.5 million for Entergy Texas.

The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the years ended December 31, 2021, 2020, and 2019 are as follows:

Instrument

Income Statement Location

Amount of gain (loss) recorded in the income statement

Registrant

(In Millions)

2021

Natural gas swaps and options

Fuel, fuel-related expenses, and gas purchased for resale

$12.6

(a)

Entergy Louisiana

Natural gas swaps

Fuel, fuel-related expenses, and gas purchased for resale

$19.8

(a)

Entergy Mississippi

Natural gas swaps

Fuel, fuel-related expenses, and gas purchased for resale

($0.1)

(a)

Entergy New Orleans

Financial transmission rights

Purchased power

$42.6

(b)

Entergy Arkansas

Financial transmission rights

Purchased power

$31.6

(b)

Entergy Louisiana

Financial transmission rights

Purchased power

$11.3

(b)

Entergy Mississippi

Financial transmission rights

Purchased power

$4.3

(b)

Entergy New Orleans

Financial transmission rights

Purchased power

$85.9

(b)

Entergy Texas

2020

Natural gas swaps

Fuel, fuel-related expenses, and gas purchased for resale

($11.1)

(a)

Entergy Mississippi

Natural gas swaps

Fuel, fuel-related expenses, and gas purchased for resale

($0.8)

(a)

Entergy New Orleans

Financial transmission rights

Purchased power

$26.7

(b)

Entergy Arkansas

Financial transmission rights

Purchased power

$19.6

(b)

Entergy Louisiana

Financial transmission rights

Purchased power

$3.0

(b)

Entergy Mississippi

Financial transmission rights

Purchased power

$1.4

(b)

Entergy New Orleans

Financial transmission rights

Purchased power

$40.4

(b)

Entergy Texas

2019

Natural gas swaps and options

Fuel, fuel-related expenses, and gas purchased for resale

($5.3)

(a)

Entergy Louisiana

Natural gas swaps

Fuel, fuel-related expenses, and gas purchased for resale

($7.7)

(a)

Entergy Mississippi

Financial transmission rights

Purchased power

$22.3

(b)

Entergy Arkansas

Financial transmission rights

Purchased power

$46.7

(b)

Entergy Louisiana

Financial transmission rights

Purchased power

$6.8

(b)

Entergy Mississippi

Financial transmission rights

Purchased power

$2.7

(b)

Entergy New Orleans

Financial transmission rights

Purchased power

$15.7

(b)

Entergy Texas

a.Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.

b.Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses

recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments.

Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value.

Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.

The three levels of the fair value hierarchy are:

•Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets. Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase.

•Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value. Level 2 inputs include the following:

–quoted prices for similar assets or liabilities in active markets;

–quoted prices for identical assets or liabilities in inactive markets;

–inputs other than quoted prices that are observable for the asset or liability; or

–inputs that are derived principally from or corroborated by observable market data by correlation or other means.

Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs.

•Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants.

The amounts reflected as the fair value of electricity swaps were based on the estimated amount that the contracts were in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and equaled the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts included cash flow hedges that swapped fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values were based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate were recorded as derivative contract assets or liabilities. For contracts that had unit contingent terms, a further discount was applied based on the historical relationship between contract and market prices for similar contract terms.

The amounts reflected as the fair values of electricity options were valued based on a Black Scholes model, and were calculated at the end of each month for accounting purposes. Inputs to the valuation included end of day forward market prices for the period when the transactions settled, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities were reviewed and could be adjusted if it was determined that there was a better representation of fair value.

On a daily basis, the Office of Corporate Risk Oversight calculated the mark-to-market for electricity swaps and options. The Office of Corporate Risk Oversight also validated forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences were analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options were also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities. Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirmed the mark-to-market calculations and prepared price scenarios and credit downgrade scenario analysis. The scenario analysis was communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis was completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In particular, the credit and liquidity effects were calculated for this analysis. This analysis was communicated to senior management within Entergy and Entergy Wholesale Commodities.

The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight. The values are calculated internally and verified against the data published by MISO. Entergy’s Entergy Wholesale Commodities Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice

President and Treasurer. The Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer.

The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2021 and December 31, 2020. The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels.

Entergy Mississippi


2021	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$47.6	$—	$—	$47.6
Escrow accounts	48.9	—	—	48.9
Financial transmission rights	—	—	0.3	0.3
	$96.5	$—	$0.3	$96.8
Liabilities:
Gas hedge contracts	$6.7	$—	$—	$6.7


2020	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Escrow accounts	$64.6	$—	$—	$64.6
Financial transmission rights	—	—	0.6	0.6
	$64.6	$—	$0.6	$65.2

Liabilities:
Gas hedge contracts	$5.0	$—	$—	$5.0

The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2021.


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)

Balance as of January 1, 2021	$2.7	$4.2	$0.6	$0.1	$1.6
Issuances of financial transmission rights	2.8	4.1	1.7	0.4	2.7
Gains (losses) included as a regulatory liability/asset	39.4	23.9	9.3	3.9	82.4
Settlements	(42.6)	(31.6)	(11.3)	(4.3)	(85.9)
Balance as of December 31, 2021	$2.3	$0.6	$0.3	$0.1	$0.8

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2020.


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)

Balance as of January 1, 2020	$3.3	$4.5	$0.8	$0.3	$0.9
Issuances of financial transmission rights	6.5	13.2	1.4	(0.1)	2.4
Gains (losses) included as a regulatory liability/asset	19.6	6.1	1.4	1.3	38.7
Settlements	(26.7)	(19.6)	(3.0)	(1.4)	(40.4)
Balance as of December 31, 2020	$2.7	$4.2	$0.6	$0.1	$1.6

NOTE 16. DECOMMISSIONING TRUST FUNDS

Note 16 to the financial statements is not applicable for Entergy Mississippi.

NOTE 17. VARIABLE INTEREST ENTITIES

Note 17 to the financial statements is not applicable to the presentation of the FERC Form 1.

NOTE 18. TRANSACTIONS WITH AFFILIATES

Each Registrant Subsidiary purchases electricity from or sells electricity to the other Registrant Subsidiaries, or both, under rate schedules filed with the FERC. The Registrant Subsidiaries receive management, technical, advisory, operating, and administrative services from Entergy Services; and receive management, technical, and operating services from Entergy Operations. These transactions are on an “at cost” basis.

As described in Note 4 to the financial statements, the Registrant Subsidiaries participate in Entergy’s money pool and earn interest income from the money pool.

The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates.

Intercompany Revenues


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Millions)
2021	$109.8	$289.9	$1.4	$—	$64.3	$545.6
2020	$105.2	$280.5	$1.2	$—	$40.4	$520.7
2019	$117.5	$277.8	$1.4	$—	$51.6	$584.1

Intercompany Operating Expenses


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Millions)
2021	$559.7	$755.2	$299.8	$287.8	$275.0	$190.8
2020	$515.5	$661.5	$283.3	$266.0	$260.3	$177.4
2019	$534.0	$665.4	$306.7	$292.1	$255.0	$156.2

Intercompany Interest and Investment Income


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
		(In Millions)

2021	$—	$127.6	$—	$—	$—	$—
2020	$—	$127.7	$0.1	$—	$—	$0.2
2019	$0.4	$128.5	$0.4	$—	$0.4	$1.0

NOTE 19. SUBSEQUENT EVENT

Management has evaluated the impact of events occurring after December 31, 2021 up to April 15, 2022, the date that Entergy Mississippi's FERC financial statements and disclosures were filed. These financial statements include all necessary adjustments and disclosures resulting from these evaluations.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

STATEMENTS OF ACCUMULATED COMPREHENSIVE INCOME, COMPREHENSIVE INCOME, AND HEDGING ACTIVITIES
Report in columns (b),(c),(d) and (e) the amounts of accumulated other comprehensive income items, on a net-of-tax basis, where appropriate. Report in columns (f) and (g) the amounts of other categories of other cash flow hedges. For each category of hedges that have been accounted for as "fair value hedges", report the accounts affected and the related amounts in a footnote. Report data on a year-to-date basis.
Line No.	Item (a)	Unrealized Gains and Losses on Available-For-Sale Securities (b)	Minimum Pension Liability Adjustment (net amount) (c)	Foreign Currency Hedges (d)	Other Adjustments (e)	Other Cash Flow Hedges Interest Rate Swaps (f)	Other Cash Flow Hedges [Specify] (g)	Totals for each category of items recorded in Account 219 (h)	Net Income (Carried Forward from Page 116, Line 78) (i)	Total Comprehensive Income (j)
1	Balance of Account 219 at Beginning of Preceding Year
2	Preceding Quarter/Year to Date Reclassifications from Account 219 to Net Income
3	Preceding Quarter/Year to Date Changes in Fair Value
4	Total (lines 2 and 3)								140,583,075
5	Balance of Account 219 at End of Preceding Quarter/Year
6	Balance of Account 219 at Beginning of Current Year
7	Current Quarter/Year to Date Reclassifications from Account 219 to Net Income
8	Current Quarter/Year to Date Changes in Fair Value
9	Total (lines 7 and 8)								166,834,143
10	Balance of Account 219 at End of Current Quarter/Year

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS FOR DEPRECIATION. AMORTIZATION AND DEPLETION
Report in Column (c) the amount for electric function, in column (d) the amount for gas function, in column (e), (f), and (g) report other (specify) and in column (h) common function.
Line No.	Classification (a)	Total Company For the Current Year/Quarter Ended (b)	Electric (c)	Gas (d)	Other (Specify) (e)	Other (Specify) (f)	Other (Specify) (g)	Common (h)
1	UtilityPlantAbstract UTILITY PLANT
2	UtilityPlantInServiceAbstract In Service
3	UtilityPlantInServiceClassified Plant in Service (Classified)	5,906,090,117	5,906,090,117
4	UtilityPlantInServicePropertyUnderCapitalLeases Property Under Capital Leases	(a) 25,945,406	25,945,406
5	UtilityPlantInServicePlantPurchasedOrSold Plant Purchased or Sold
6	UtilityPlantInServiceCompletedConstructionNotClassified Completed Construction not Classified	600,520,068	600,520,068
7	UtilityPlantInServiceExperimentalPlantUnclassified Experimental Plant Unclassified
8	UtilityPlantInServiceClassifiedAndUnclassified Total (3 thru 7)	6,532,555,591	6,532,555,591
9	UtilityPlantLeasedToOthers Leased to Others
10	UtilityPlantHeldForFutureUse Held for Future Use	220,455	220,455
11	ConstructionWorkInProgress Construction Work in Progress	95,935,092	95,935,092
12	UtilityPlantAcquisitionAdjustment Acquisition Adjustments	83,828,314	83,828,314
13	UtilityPlantAndConstructionWorkInProgress Total Utility Plant (8 thru 12)	6,712,539,452	6,712,539,452
14	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Accumulated Provisions for Depreciation, Amortization, & Depletion	(b) 1,991,077,854	1,991,077,854
15	UtilityPlantNet Net Utility Plant (13 less 14)	4,721,461,598	4,721,461,598
16	DetailOfAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION
17	AccumulatedProvisionForDepreciationAmortizationAndDepletionUtilityPlantInServiceAbstract In Service:
18	DepreciationUtilityPlantInService Depreciation	1,757,306,960	1,757,306,960
19	AmortizationAndDepletionOfProducingNaturalGasLandAndLandRightsutilityPlantInService Amortization and Depletion of Producing Natural Gas Land and Land Rights
20	AmortizationOfUndergroundStorageLandAndLandRightsutilityPlantInService Amortization of Underground Storage Land and Land Rights
21	AmortizationOfOtherUtilityPlantUtilityPlantInService Amortization of Other Utility Plant	(c) 215,967,038	215,967,038
22	DepreciationAmortizationAndDepletionUtilityPlantInService Total in Service (18 thru 21)	1,973,273,998	1,973,273,998
23	DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthersAbstract Leased to Others
24	DepreciationUtilityPlantLeasedToOthers Depreciation
25	AmortizationAndDepletionUtilityPlantLeasedToOthers Amortization and Depletion
26	DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthers Total Leased to Others (24 & 25)
27	DepreciationAndAmortizationUtilityPlantHeldForFutureUseAbstract Held for Future Use
28	DepreciationUtilityPlantHeldForFutureUse Depreciation	6,808	6,808
29	AmortizationUtilityPlantHeldForFutureUse Amortization
30	DepreciationAndAmortizationUtilityPlantHeldForFutureUse Total Held for Future Use (28 & 29)	6,808	6,808
31	AbandonmentOfLeases Abandonment of Leases (Natural Gas)
32	AmortizationOfPlantAcquisitionAdjustment Amortization of Plant Acquisition Adjustment	17,797,048	17,797,048
33	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Total Accum Prov (equals 14) (22,26,30,31,32)	(d) 1,991,077,854	1,991,077,854

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: UtilityPlantInServicePropertyUnderCapitalLeases

Includes Operating Leases recorded in accordance with FASB ASU No. 2016-02, Leases, as provided for in FERC Docket No. AI19-1-000.

(b) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility

Includes a debit balance for removal costs of $136,760,640.

(c) Concept: AmortizationOfOtherUtilityPlantUtilityPlantInService

Includes accumulated provision for amortization of intangible assets.

(d) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility

Includes a debit balance for removal costs of $136,760,640.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

NUCLEAR FUEL MATERIALS (Account 120.1 through 120.6 and 157)
Report below the costs incurred for nuclear fuel materials in process of fabrication, on hand, in reactor, and in cooling; owned by the respondent. If the nuclear fuel stock is obtained under leasing arrangements, attach a statement showing the amount of nuclear fuel leased, the quantity used and quantity on hand, and the costs incurred under such leasing arrangements.
Line No.	Description of item (a)	Balance Beginning of Year (b)	Changes during Year Additions (c)	Changes during Year Amortization (d)	Changes during Year Other Reductions (Explain in a footnote) (e)	Balance End of Year (f)
1	Nuclear Fuel in process of Refinement, Conv, Enrichment & Fab (120.1)
2	Fabrication
3	Nuclear Materials
4	Allowance for Funds Used during Construction
5	(Other Overhead Construction Costs, provide details in footnote)
6	SUBTOTAL (Total 2 thru 5)
7	Nuclear Fuel Materials and Assemblies
8	In Stock (120.2)
9	In Reactor (120.3)
10	SUBTOTAL (Total 8 & 9)
11	Spent Nuclear Fuel (120.4)
12	Nuclear Fuel Under Capital Leases (120.6)
13	(Less) Accum Prov for Amortization of Nuclear Fuel Assem (120.5)
14	TOTAL Nuclear Fuel Stock (Total 6, 10, 11, 12, less 13)
15	Estimated Net Salvage Value of Nuclear Materials in Line 9
16	Estimated Net Salvage Value of Nuclear Materials in Line 11
17	Est Net Salvage Value of Nuclear Materials in Chemical Processing
18	Nuclear Materials held for Sale (157)
19	Uranium
20	Plutonium
21	Other (Provide details in footnote)
22	TOTAL Nuclear Materials held for Sale (Total 19, 20, and 21)

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

ELECTRIC PLANT IN SERVICE (Account 101, 102, 103 and 106)
Report below the original cost of electric plant in service according to the prescribed accounts. In addition to Account 101, Electric Plant in Service (Classified), this page and the next include Account 102, Electric Plant Purchased or Sold; Account 103, Experimental Electric Plant Unclassified; and Account 106, Completed Construction Not Classified-Electric. Include in column (c) or (d), as appropriate, corrections of additions and retirements for the current or preceding year. For revisions to the amount of initial asset retirement costs capitalized, included by primary plant account, increases in column (c) additions and reductions in column (e) adjustments. Enclose in parentheses credit adjustments of plant accounts to indicate the negative effect of such accounts. Classify Account 106 according to prescribed accounts, on an estimated basis if necessary, and include the entries in column (c). Also to be included in column (c) are entries for reversals of tentative distributions of the prior year reported in column (b). Likewise, if the respondent has a significant amount of plant retirements which have not been classified to primary accounts at the end of the year, include in column (d) a tentative distribution of such retirements, on an estimated basis, with appropriate contra entry to the account for accumulated depreciation provision. Include also in column (d) distributions of these tentative classifications in columns (c) and (d), including the reversals of the prior years tentative account distributions of these amounts. Careful observance of the above instructions and the texts of Accounts 101 and 106 will avoid serious omissions of the reported amount of respondent’s plant actually in service at end of year. Show in column (f) reclassifications or transfers within utility plant accounts. Include also in column (f) the additions or reductions of primary account classifications arising from distribution of amounts initially recorded in Account 102, include in column (e) the amounts with respect to accumulated provision for depreciation, acquisition adjustments, etc., and show in column (f) only the offset to the debits or credits distributed in column (f) to primary account classifications. For Account 399, state the nature and use of plant included in this account and if substantial in amount submit a supplementary statement showing subaccount classification of such plant conforming to the requirement of these pages. For each amount comprising the reported balance and changes in Account 102, state the property purchased or sold, name of vendor or purchase, and date of transaction. If proposed journal entries have been filed with the Commission as required by the Uniform System of Accounts, give also date.
Line No.	Account (a)	Balance Beginning of Year (b)	Additions (c)	Retirements (d)	Adjustments (e)	Transfers (f)	Balance at End of Year (g)
1	1. INTANGIBLE PLANT
2	(301) Organization
3	(302) Franchise and Consents
4	(303) Miscellaneous Intangible Plant	326,218,182	28,787,361	58,968			354,946,575
5	TOTAL Intangible Plant (Enter Total of lines 2, 3, and 4)	326,218,182	28,787,361	58,968			354,946,575
6	2. PRODUCTION PLANT
7	A. Steam Production Plant
8	(310) Land and Land Rights	2,270,414					2,270,414
9	(311) Structures and Improvements	64,879,160	1,699,033	281,967			66,296,226
10	(312) Boiler Plant Equipment	308,407,922	6,862,747	3,007,082			312,263,587
11	(313) Engines and Engine-Driven Generators
12	(314) Turbogenerator Units	120,931,232	24,871,379	2,013,380			143,789,231
13	(315) Accessory Electric Equipment	46,062,812	1,978,661	343,681			47,697,792
14	(316) Misc. Power Plant Equipment	10,117,004	887,642	2,092			11,002,554
15	(317) Asset Retirement Costs for Steam Production	2,008,212					2,008,212
16	TOTAL Steam Production Plant (Enter Total of lines 8 thru 15)	554,676,756	36,299,462	5,648,202			585,328,016
17	B. Nuclear Production Plant
18	(320) Land and Land Rights
19	(321) Structures and Improvements
20	(322) Reactor Plant Equipment
21	(323) Turbogenerator Units
22	(324) Accessory Electric Equipment
23	(325) Misc. Power Plant Equipment
24	(326) Asset Retirement Costs for Nuclear Production
25	TOTAL Nuclear Production Plant (Enter Total of lines 18 thru 24)
26	C. Hydraulic Production Plant
27	(330) Land and Land Rights
28	(331) Structures and Improvements
29	(332) Reservoirs, Dams, and Waterways
30	(333) Water Wheels, Turbines, and Generators
31	(334) Accessory Electric Equipment
32	(335) Misc. Power Plant Equipment
33	(336) Roads, Railroads, and Bridges
34	(337) Asset Retirement Costs for Hydraulic Production
35	TOTAL Hydraulic Production Plant (Enter Total of lines 27 thru 34)
36	D. Other Production Plant
37	(340) Land and Land Rights	4,253,086					4,253,086
38	(341) Structures and Improvements	327,672,974	3,440,949	337,266			330,776,657
39	(342) Fuel Holders, Products, and Accessories	8,501,212	148,644	4,779			8,645,077
40	(343) Prime Movers	325,928,125	22,400,202	7,245,069		8,029,768	349,113,026
41	(344) Generators	237,880,612	4,720,705	1,523,895		8,029,768	233,047,654
42	(345) Accessory Electric Equipment	44,307,525	2,208,780	9,701			46,506,604
43	(346) Misc. Power Plant Equipment	6,371,538	238,626				6,610,164
44	(347) Asset Retirement Costs for Other Production
44.1	(348) Energy Storage Equipment - Production
45	TOTAL Other Prod. Plant (Enter Total of lines 37 thru 44)	954,915,072	33,157,906	9,120,710			978,952,268
46	TOTAL Prod. Plant (Enter Total of lines 16, 25, 35, and 45)	1,509,591,828	69,457,368	14,768,912			1,564,280,284
47	3. Transmission Plant
48	(350) Land and Land Rights	94,945,012	8,603,506	175			103,548,343
48.1	(351) Energy Storage Equipment - Transmission
49	(352) Structures and Improvements	62,561,654	5,204,268	132,387		862	67,632,673
50	(353) Station Equipment	672,804,435	71,864,750	4,020,034		49,766	740,599,385
51	(354) Towers and Fixtures	56,676,823		16,720			56,660,103
52	(355) Poles and Fixtures	440,645,994	72,530,133	1,386,656			511,789,471
53	(356) Overhead Conductors and Devices	313,901,263	17,697,322	1,336,365			330,262,220
54	(357) Underground Conduit	1,311					1,311
55	(358) Underground Conductors and Devices	6,310					6,310
56	(359) Roads and Trails
57	(359.1) Asset Retirement Costs for Transmission Plant
58	TOTAL Transmission Plant (Enter Total of lines 48 thru 57)	1,641,542,802	175,899,979	6,892,337		50,628	1,810,499,816
59	4. Distribution Plant
60	(360) Land and Land Rights	17,685,533	3,465,675	7,457			21,143,751
61	(361) Structures and Improvements	19,293,682	3,902,524	33,454		862	23,163,614
62	(362) Station Equipment	378,653,992	30,733,556	3,596,480		1,335,794	404,455,274
63	(363) Energy Storage Equipment – Distribution
64	(364) Poles, Towers, and Fixtures	361,934,674	59,932,393	6,267,692		21,952	415,577,423
65	(365) Overhead Conductors and Devices	466,188,994	48,684,163	8,699,709		13,649	506,159,799
66	(366) Underground Conduit	47,548,175	4,256,972	66,073		99	51,739,173
67	(367) Underground Conductors and Devices	95,126,350	9,407,734	1,236,319		915,768	104,213,533
68	(368) Line Transformers	533,023,989	83,833,543	6,959,061		14,636	609,883,835
69	(369) Services	183,057,701	6,997,850	577,770		892,127	190,369,908
70	(370) Meters	96,158,415	33,980,366	9,258,485		401,181	120,479,115
71	(371) Installations on Customer Premises	45,999,388	4,213,919	8,691,596			41,521,711
72	(372) Leased Property on Customer Premises
73	(373) Street Lighting and Signal Systems	76,215,162	12,924,762	2,814,064			86,325,860
74	(374) Asset Retirement Costs for Distribution Plant
75	TOTAL Distribution Plant (Enter Total of lines 60 thru 74)	2,320,886,055	302,333,457	48,208,160		21,644	2,575,032,996
76	5. REGIONAL TRANSMISSION AND MARKET OPERATION PLANT
77	(380) Land and Land Rights
78	(381) Structures and Improvements
79	(382) Computer Hardware
80	(383) Computer Software
81	(384) Communication Equipment
82	(385) Miscellaneous Regional Transmission and Market Operation Plant
83	(386) Asset Retirement Costs for Regional Transmission and Market Oper
84	TOTAL Transmission and Market Operation Plant (Total lines 77 thru 83)
85	6. General Plant
86	(389) Land and Land Rights	7,253,860	581,832				7,835,692
87	(390) Structures and Improvements	111,325,150	8,703,441	490,549			119,538,042
88	(391) Office Furniture and Equipment	21,641,207	2,846,349	3,960,633		445,244	20,081,679
89	(392) Transportation Equipment	261,640					261,640
90	(393) Stores Equipment		12,348				12,348
91	(394) Tools, Shop and Garage Equipment	7,327,505	1,001,002				8,328,507
92	(395) Laboratory Equipment	4,337,373	74,940				4,412,313
93	(396) Power Operated Equipment		64,407				64,407
94	(397) Communication Equipment	26,730,705	12,410,636			474,228	39,615,569
95	(398) Miscellaneous Equipment	1,593,368	106,949				1,700,317
96	SUBTOTAL (Enter Total of lines 86 thru 95)	180,470,808	25,801,904	4,451,182		28,984	201,850,514
97	(399) Other Tangible Property
98	(399.1) Asset Retirement Costs for General Plant
99	TOTAL General Plant (Enter Total of lines 96, 97, and 98)	180,470,808	25,801,904	4,451,182		28,984	201,850,514
100	TOTAL (Accounts 101 and 106)	5,978,709,675	602,280,069	74,379,559			6,506,610,185
101	(102) Electric Plant Purchased (See Instr. 8)
102	(Less) (102) Electric Plant Sold (See Instr. 8)
103	(103) Experimental Plant Unclassified
104	TOTAL Electric Plant in Service (Enter Total of lines 100 thru 103)	5,978,709,675	602,280,069	74,379,559			6,506,610,185

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

ELECTRIC PLANT LEASED TO OTHERS (Account 104)
Line No.	LesseeName Name of Lessee (a)	IndicationOfAssociatedCompany * (Designation of Associated Company) (b)	LeaseDescription Description of Property Leased (c)	CommissionAuthorization Commission Authorization (d)	ExpirationDateOfLease Expiration Date of Lease (e)	ElectricPlantLeasedToOthers Balance at End of Year (f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47	TOTAL

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

ELECTRIC PLANT HELD FOR FUTURE USE (Account 105)
Report separately each property held for future use at end of the year having an original cost of $250,000 or more. Group other items of property held for future use. For property having an original cost of $250,000 or more previously used in utility operations, now held for future use, give in column (a), in addition to other required information, the date that utility use of such property was discontinued, and the date the original cost was transferred to Account 105.
Line No.	ElectricPlantHeldForFutureUseDescription Description and Location of Property (a)	ElectricPlantPropertyClassifiedAsHeldForFutureUseOriginalDate Date Originally Included in This Account (b)	ElectricPlantPropertyClassifiedAsHeldForFutureUseExpectedUseInServiceDate Date Expected to be used in Utility Service (c)	ElectricPlantHeldForFutureUse Balance at End of Year (d)
1	Land and Rights:
2	Land and Land Rights Under $250,000			220,455
21	Other Property:
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47	TOTAL			220,455

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

CONSTRUCTION WORK IN PROGRESS - - ELECTRIC (Account 107)
Report below descriptions and balances at end of year of projects in process of construction (107). Show items relating to "research, development, and demonstration" projects last, under a caption Research, Development, and Demonstrating (see Account 107 of the Uniform System of Accounts). Minor projects (5% of the Balance End of the Year for Account 107 or $1,000,000, whichever is less) may be grouped.
Line No.	ConstructionWorkInProgressProjectDescription Description of Project (a)	ConstructionWorkInProgress Construction work in progress - Electric (Account 107) (b)
1	2020 - Jackson North - Jackson Nort	181,088
2	2020 - MADISON - CANTON - 6C07 - QF	168,077
3	2020 - Madison-Yandell-GY01 & GY05-	284,520
4	2020 - RANKIN - AIRPORT - 6A04 - 55	314,271
5	2020 - SOUTHAVEN - PLUM POINT - CHU	281,754
6	2020 - VICKSBURG - VICKSBURG EAST -	448,698
7	2020 Focus 6R02 FC20M051 Rankin Rou	187,338
8	2020 Planning CL20-005V New Build N	260,306
9	2020 Planning CL20-005V Rebuild R1	114,116
10	2020 Planning CL20-005V Rep A1, RRE	378,517
11	2020 Planning RK20-010V Rebuild R2	425,921
12	2020 Planning SE17-012A Regs/RC RRE	130,581
13	2020 Planning SH20-005V Getwell - E	144,428
14	2020-Madison-Hoy Rd-Natchez Trace @	925,706
15	2020-Rankin-Henderson Rd-E Metro Pk	315,348
16	2020-SuccessAudit-SA20M011-Southave	125,642
17	2021 - Cleveland - Belzoni - 4H01 -	126,575
18	2021 - Jackson Downtown UG Network	104,942
19	2021 - Midstate - Kosciusko - Insta	987,641
20	2021 FOCUS FC21M021 Natchez 8F05 Ro	103,355
21	2021 Planning CV20-002A New Build N	120,913
22	2021 RANKIN MORTON 6R02 55Q0022	216,061
23	2021 SHN JXSNSW-KINGSW - 2 RCs	124,497
24	2021-Magee-Mendenhall-Relocate Faci	367,973
25	Add Ckt. 9A06 to Poleline for Seco	134,333
26	Clinton - Phase 1 / District 6-City	102,634
27	DeSoto County-Ross Meadows Land-M&R	108,721
28	2022-Vicksburg-Glass Road	157,421
29	Downtown Jackson - Replace 1500 KVA	145,662
30	Downtown Jackson - Replace 500 KVA	134,367
31	EMI 2021 Dec Storm	457,911
32	FC20M036 - FOCUS - 8F05 - FJ669	149,160
33	FC21M010 - FOCUS - FP02 - FP02	129,013
34	FLI-SENATOBIA NETWORK-SENATOBIA-1H0	137,443
35	FP# F1PPU27609-Brookhaven-West McCo	227,213
36	FP# F1PPU27609-FLI-Brookhaven-West	172,975
37	GM-39-3E08-C4 Capacitor Install Ree	185,884
38	GM-39-3E08-REBUILD 3PH-NURSING HOME	221,571
39	GM-39-3R02-C11 Capacitor Install Hi	182,995
40	GM-39-3R02-RC7 Capacitor removal Hi	147,969
41	GM-Guild 33-FA06-Rebuild-Cleary Rd	154,677
42	GM-Guild 33-GK01-Asset Op-Cap Bank	278,241
43	GM-Guild 33-GK01-Focus Rebuild-Fore	277,342
44	GM-Guild 33-GK01-Rebuild-Brookwood	121,881
45	GM-Vicksburg SE Guild 5F03-N6, FSW1	856,154
46	HERNANDO - 251 HWY 51 N - ASSOCIATE	123,400
47	Highway 51 Warehouse Relocation	147,261
48	Horn Lake-MS Hwy 301-Yazoo Developm	153,249
49	Horn Lake-Nail Road-Reiner Developm	111,030
50	HWY-2020-GM01-DF400-BOZEMAN RD OH 1	250,811
51	Jackson - Hwy LED Lighting	168,084
52	Madison-Hwy 43-Expedition Point Dev	129,200
53	MIDWAY RD IMPROVEMENT PROJECT - CLI	182,723
54	Natchez Trace @ Hwy 43 UG Installa	284,506
55	Nesbit-Laughter Road-Bridgforth Pro	119,028
56	Rankin -- Permanent Svc to Communit	123,104
57	Relocate Facilities W Capitol St	125,806
58	SNOWDEN PARK DIST. ROW	149,366
59	T&D - Catlett 230kv Sub - Substatio	483,560
60	T&D - Flora Add Transformer - North	342,357
61	T&D - Flora Add Transformer - West	129,286
62	T&D 2021 Rankin UG - N1	233,221
63	Winona-623 SAWYER RD EXT WINONA,MS-	606,905
64	WINONA-SAWYER RD BIEWER LUMBER 2R04	454,453
65	WINONA-SAWYER RD-BIEWER LUMBER-EXTE	552,460
66	Other distribution lines plant	8,977,290
67	Advanced DMS	132,218
68	AMI - DMS/OMS - Software - Rel 4-5	1,166,752
69	AMI Sales and Rev BIE	238,570
70	Asset Suite/AIMM Repl - Supply Chai	5,892,167
71	CSD Workforce Management System	290,835
72	Deposit Alternative Pay	359,052
73	Digital LIHEAP	179,994
74	EML Public EV Charging Pilot	111,636
75	HER - New Desoto Service Center	8,664,582
76	MS Trans Off/Stor Facility Design	186,119
77	Power Generation Fleet Training Pla	263,024
78	SAISO Replacement	240,601
79	ServiceNow Enhancements	104,516
80	SW2 - EDE-Bill Syst Contr Repo Inte	191,797
81	Utility Data Warehouse Plus	250,957
82	Other general and intangible plant	1,002,008
83	A1A - GE LTSA Budget Cap 2020-2024	7,537,668
84	EMI Sunflower County SolarOversight	1,439,690
85	GA1 WaterWallTube & Furn Hopp Botto	219,306
86	GMS -ERDC Back-up Generator	3,440,806
87	HN1 - Hinds LTSA Capital	5,594,676
88	SPO EMISunflowerCoSolarBOTTransactn	2,247,762
89	SPO EML SunflowerTaxEquityPartneshp	822,468
90	Other production plant	96,375
91	Brookhaven Upgrade Transformer	243,078
92	Build Pine Tree 230/12.47kV Sub	515,863
93	BWSES: J2200 AT1 Spare Life Extend	228,030
94	Byram Replace Breaker FJ04	154,229
95	Byram replace FJ05 & RTU Grid Mod	225,504
96	Clinton Ind: rpl Ckt Sw & Upgd Bay	302,564
97	Crenshaw: Add Circuit Switcher	163,217
98	EML C Spire - Northern Route	404,398
99	EML: 115-13.8 \| 20MVA (Marvell)	254,181
100	EML:115-4.16 \| 12.5MVA \| JTreatment	297,538
101	Fannin Rd: add Fdr Bkr Amp Transduc	341,192
102	Florence: Capacitors (54) on CapBk	120,841
103	Franklin 500kV Reconfiguration	8,127,763
104	Franklin: AT1 Cph/Spare Life Extend	431,407
105	Gallatin: rpl FX20 & add FX10 Fdr	187,994
106	GGNS: E&D ST-21 Xfmr Bay Upgd	457,530
107	Greenville Replace Breaker 3E08, J4	289,280
108	Greenville SE Install circuit sw. o	248,340
109	Hazlehurst add circuit switchers	508,806
110	Hollandale: E&D 3J22 & 02 Bkr Rpl	101,258
111	Indianola: E&D J3110 Xfmr Bay Upgd	928,031
112	Jackson, S: E&D J4674 Bay Upgrade	230,453
113	Jackson, W: rpl RTU	125,885
114	Johns-Manville: E&D J0467 Bay Upgd	514,317
115	Midnight: rpl ABS J0348 & Steel Bus	154,507
116	Northpark: Add 230/115kV-400MVA Aut	1,361,921
117	Pickens replace breaker J1708, line	292,045
118	Raleigh 115kV Sub - Add 2nd Transf	450,221
119	Rankin 115kV Sub - Add Line Bay	169,517
120	Schlater 115kV Station: Add Brkrs	4,121,815
121	Snowden Park-Bld 115kV Sub-Scoping	1,754,944
122	Whitfield: add Ckt Sw, rpl T1 Diff	135,330
123	Yandell Sub Upgrades	437,255
124	Other transmission and distribution substation plant	1,470,048
125	Bowling Green - Durant 115kV CAP	136,431
126	C6PPTM2110: Brookhaven - Wesson 115	1,063,976
127	E. Vicksburg-E. Vicksburg 115kV CAP	117,870
128	Franklin-GGNS 500Kv Phase Swa	305,628
129	Getwell-Twinkletown 230kV Cut-In	602,482
130	Greenbrook to Snowden Park 115kv Ln	120,765
131	Greenville TCEPA - Arcola 115kV CAP	228,884
132	Greenwood-Itta Bena 115Kv Cut-In	158,883
133	Indianola-Itta Bena 115kv	318,834
134	Lakeover-Hinds 230kV CAP	283,116
135	Pelahatchie - Rankin 115kV CAP	165,632
136	Other transmission lines plant	210,043
137	Undistributed overhead	630,732
43	Total	95,935,092

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

ACCUMULATED PROVISION FOR DEPRECIATION OF ELECTRIC UTILITY PLANT (Account 108)
Explain in a footnote any important adjustments during year. Explain in a footnote any difference between the amount for book cost of plant retired, Line 12, column (c), and that reported for electric plant in service, page 204, column (d), excluding retirements of non-depreciable property. The provisions of Account 108 in the Uniform System of Accounts require that retirements of depreciable plant be recorded when such plant is removed from service. If the respondent has a significant amount of plant retired at year end which has not been recorded and/or classified to the various reserve functional classifications, make preliminary closing entries to tentatively functionalize the book cost of the plant retired. In addition, include all costs included in retirement work in progress at year end in the appropriate functional classifications. Show separately interest credits under a sinking fund or similar method of depreciation accounting.
Line No.	Item (a)	Total (c + d + e) (b)	Electric Plant in Service (c)	Electric Plant Held for Future Use (d)	Electric Plant Leased To Others (e)
Section A. Balances and Changes During Year
1	AccumulatedProvisionForDepreciationOfElectricUtilityPlant Balance Beginning of Year	1,687,320,379	1,687,313,571	6,808
2	Depreciation Provisions for Year, Charged to
3	DepreciationExpenseExcludingAdjustments (403) Depreciation Expense	199,709,644	(a) 199,709,644
4	DepreciationExpenseForAssetRetirementCosts (403.1) Depreciation Expense for Asset Retirement Costs	11,486	11,486
5	ExpensesOfElectricPlantLeasedToOthers (413) Exp. of Elec. Plt. Leas. to Others
6	TransportationExpensesClearing Transportation Expenses-Clearing
7	OtherClearingAccounts Other Clearing Accounts
8	OtherAccounts Other Accounts (Specify, details in footnote):
9.1	Other Accounts (Specify, details in footnote):	17,858	(b) 17,858
10	DepreciationProvision TOTAL Deprec. Prov for Year (Enter Total of lines 3 thru 9)	199,738,988	199,738,988
11	Net Charges for Plant Retired:
12	BookCostOfRetiredPlant Book Cost of Plant Retired	74,320,590	(c) 74,320,590
13	CostOfRemovalOfPlant Cost of Removal	58,585,284	58,585,284
14	SalvageValueOfRetiredPlant Salvage (Credit)	3,255,287	3,255,287
15	NetChargesForRetiredPlant TOTAL Net Chrgs. for Plant Ret. (Enter Total of lines 12 thru 14)	129,650,587	129,650,587
16	OtherAdjustmentsToAccumulatedDepreciation Other Debit or Cr. Items (Describe, details in footnote):
17.1	Other Debit or Cr. Items (Describe, details in footnote):	95,012	(d) 95,012
18	BookCostOfAssetRetirementCosts Book Cost or Asset Retirement Costs Retired
19	AccumulatedProvisionForDepreciationOfElectricUtilityPlant Balance End of Year (Enter Totals of lines 1, 10, 15, 16, and 18)	1,757,313,768	1,757,306,960	6,808
Section B. Balances at End of Year According to Functional Classification
20	AccumulatedDepreciationSteamProduction Steam Production	396,439,449	396,437,064	2,385
21	AccumulatedDepreciationNuclearProduction Nuclear Production
22	AccumulatedDepreciationHydraulicProductionConventional Hydraulic Production-Conventional
23	AccumulatedDepreciationHydraulicProductionPumpedStorage Hydraulic Production-Pumped Storage
24	AccumulatedDepreciationOtherProduction Other Production	365,623,550	365,623,550
25	AccumulatedDepreciationTransmission Transmission	438,853,295	438,848,872	4,423
26	AccumulatedDepreciationDistribution Distribution	533,623,234	533,623,234
27	AccumulatedDepreciationRegionalTransmissionAndMarketOperation Regional Transmission and Market Operation
28	AccumulatedDepreciationGeneral General	22,774,240	22,774,240
29	AccumulatedProvisionForDepreciationOfElectricUtilityPlant TOTAL (Enter Total of lines 20 thru 28)	1,757,313,768	1,757,306,960	6,808

FOOTNOTE DATA

(a) Concept: DepreciationExpenseExcludingAdjustments

Excludes service company depreciation allocations of $3,207,942 (included in the depreciation expense shown on page 336), since these allocations do not offset to accumulated reserves.

(b) Concept: OtherAccounts

Includes depreciation on Gerald Andrus pipelines and Independence, which is accounted for as fuel expense.

(c) Concept: BookCostOfRetiredPlant

Excludes retirements of $58,969 (included in Amortization of Other Utility Plant shown on pages 204 - 207), since these retirements do not offset to accumulated depreciation reserves.

(d) Concept: OtherAdjustmentsToAccumulatedDepreciation


Sale of Land - Nesbit			($14,912)
Sale of Land - Plum Point			(80,275)
Sale of Land - Tillatoba			175
Total			($95,012)

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1)
Report below investments in Account 123.1, Investments in Subsidiary Companies. Provide a subheading for each company and list thereunder the information called for below. Sub-TOTAL by company and give a TOTAL in columns (e), (f), (g) and (h). (a) Investment in Securities - List and describe each security owned. For bonds give also principal amount, date of issue, maturity, and interest rate. (b) Investment Advances - Report separately the amounts of loans or investment advances which are subject to repayment, but which are not subject to current settlement. With respect to each advance show whether the advance is a note or open account. List each note giving date of issuance, maturity date, and specifying whether note is a renewal. Report separately the equity in undistributed subsidiary earnings since acquisition. The TOTAL in column (e) should equal the amount entered for Account 418.1. For any securities, notes, or accounts that were pledged designate such securities, notes, or accounts in a footnote, and state the name of pledgee and purpose of the pledge. If Commission approval was required for any advance made or security acquired, designate such fact in a footnote and give name of Commission, date of authorization, and case or docket number. Report column (f) interest and dividend revenues from investments, including such revenues from securities disposed of during the year. In column (h) report for each investment disposed of during the year, the gain or loss represented by the difference between cost of the investment (or the other amount at which carried in the books of account if different from cost) and the selling price thereof, not including interest adjustment includible in column (f). Report on Line 42, column (a) the TOTAL cost of Account 123.1.
Line No.	DescriptionOfInvestmentsInSubsidiaryCompanies Description of Investment (a)	DateOfAcquisitionInvestmentsInSubsidiaryCompanies Date Acquired (b)	DateOfMaturityInvestmentsInSubsidiaryCompanies Date of Maturity (c)	InvestmentInSubsidiaryCompanies Amount of Investment at Beginning of Year (d)	EquityInEarningsOfSubsidiaryCompanies Equity in Subsidiary Earnings of Year (e)	InterestAndDividendRevenueFromInvestments Revenues for Year (f)	InvestmentInSubsidiaryCompanies Amount of Investment at End of Year (g)	InvestmentGainLossOnDisplosal Gain or Loss from Investment Disposed of (h)
1	EMI New Nuclear, LLC - Subsidiary Company Subheading	09/18/2008
2	EMI New Nuclear, LLC - Capital Contribution			14,000		8,305	5,695
3	EMI New Nuclear, LLC - Unappropriated Undistributed Subsidiary Earnings			3,695			3,695
4	EMI New Nuclear, LLC - Subtotal			10,305		8,305	2,000
5	Mississippi Power & Light Co. - Subsidiary Company Subheading
6	Mississippi Power & Light Co. - Capital Contribution			517			517
7	Mississippi Power & Light Co. - Unappropriated Undistributed Subsidiary Earnings			275			275
8	Mississippi Power & Light Co. - Subtotal			242			242
42	Total Cost of Account 123.1 $		Total	10,547		8,305	2,242

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

MATERIALS AND SUPPLIES
For Account 154, report the amount of plant materials and operating supplies under the primary functional classifications as indicated in column (a); estimates of amounts by function are acceptable. In column (d), designate the department or departments which use the class of material. Give an explanation of important inventory adjustments during the year (in a footnote) showing general classes of material and supplies and the various accounts (operating expenses, clearing accounts, plant, etc.) affected debited or credited. Show separately debit or credits to stores expense clearing, if applicable.
Line No.	Account (a)	Balance Beginning of Year (b)	Balance End of Year (c)	Department or Departments which Use Material (d)
1	Fuel Stock (Account 151)	17,004,333	10,290,914
2	Fuel Stock Expenses Undistributed (Account 152)	66,020
3	Residuals and Extracted Products (Account 153)
4	Plant Materials and Operating Supplies (Account 154)
5	Assigned to - Construction (Estimated)	(a) 41,356,038	(b) 56,438,756	Electric
6	Assigned to - Operations and Maintenance
7	Production Plant (Estimated)	13,580,542	8,799,360	Electric
8	Transmission Plant (Estimated)	74,584	112,746	Electric
9	Distribution Plant (Estimated)	549,370	777,069	Electric
10	Regional Transmission and Market Operation Plant (Estimated)
11	Assigned to - Other (provide details in footnote)
12	TOTAL Account 154 (Enter Total of lines 5 thru 11)	55,560,534	66,127,931
13	Merchandise (Account 155)
14	Other Materials and Supplies (Account 156)
15	Nuclear Materials Held for Sale (Account 157) (Not applic to Gas Util)
16	Stores Expense Undistributed (Account 163)	3,981,225	3,510,746
17
18
19
20	TOTAL Materials and Supplies	76,612,112	79,929,591

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: PlantMaterialsAndOperatingSuppliesConstruction


			BALANCE AT
			BEG OF YEAR
Production (estimated)			$21,944,092
Transmission (estimated)			3,756,915
Distribution (estimated)			15,655,031
Total Assigned to Construction (estimated)			$41,356,038

(b) Concept: PlantMaterialsAndOperatingSuppliesConstruction


			BALANCE AT
			END OF YEAR
Production (estimated)			$29,883,419
Transmission (estimated)			6,207,344
Distribution (estimated)			20,347,993
Total Assigned to Construction (estimated)			$56,438,756

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

Allowances (Accounts 158.1 and 158.2)
Report below the particulars (details) called for concerning allowances. Report all acquisitions of allowances at cost. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k). Report on Line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40. Report on Line 5 allowances returned by the EPA. Report on Line 39 the EPA’s sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA’s sale or auction of the withheld allowances. Report on Lines 8-14 the names of vendors/transferors of allowances acquired and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts). Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
		Current Year		Year One		Year Two		Year Three		Future Years		Totals
Line No.	SO2 Allowances Inventory (Account 158.1) (a)	No. (b)	Amt. (c)	No. (d)	Amt. (e)	No. (f)	Amt. (g)	No. (h)	Amt. (i)	No. (j)	Amt. (k)	No. (l)	Amt. (m)
1	Balance-Beginning of Year	150,710										150,710
2
3	Acquired During Year:
4	Issued (Less Withheld Allow)	15,931		15,930		15,930		15,930		(a) 446,047		509,768	0
5	Returned by EPA
6
7
8	Purchases/Transfers:	75										75
9
10
11
12
13
14
15	Total	75										75
16
17	Relinquished During Year:
18	Charges to Account 509
19	Other:
20	Allowances Used
20.1	Allowances Used
21	Cost of Sales/Transfers:
22	Compliance Deduction	2,787										2,787
23
24
25
26
27
28	Total	2,787										2,787
29	Balance-End of Year	163,929		15,930		15,930		15,930		446,047		657,766
30
31	Sales:
32	Net Sales Proceeds(Assoc. Co.)
33	Net Sales Proceeds (Other)
34	Gains
35	Losses
	Allowances Withheld (Acct 158.2)
36	Balance-Beginning of Year
37	Add: Withheld by EPA
38	Deduct: Returned by EPA
39	Cost of Sales
40	Balance-End of Year
41
42	Sales
43	Net Sales Proceeds (Assoc. Co.)
44	Net Sales Proceeds (Other)
45	Gains
46	Losses

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: AllowancesIssuedLessWithheldAllowancesNumber

Future years include allowances issued from 2025 through 2052.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

Allowances (Accounts 158.1 and 158.2)
Report below the particulars (details) called for concerning allowances. Report all acquisitions of allowances at cost. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k). Report on Line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40. Report on Line 5 allowances returned by the EPA. Report on Line 39 the EPA’s sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA’s sale or auction of the withheld allowances. Report on Lines 8-14 the names of vendors/transferors of allowances acquired and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts). Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
		Current Year		Year One		Year Two		Year Three		Future Years		Totals
Line No.	NOx Allowances Inventory (Account 158.1) (a)	No. (b)	Amt. (c)	No. (d)	Amt. (e)	No. (f)	Amt. (g)	No. (h)	Amt. (i)	No. (j)	Amt. (k)	No. (l)	Amt. (m)
1	Balance-Beginning of Year	154	46,554									154	46,554
2
3	Acquired During Year:
4	Issued (Less Withheld Allow)	2,316		2,267		2,267		2,267		(a) 4,534		13,651
5	Returned by EPA	92										92
6
7
8	Purchases/Transfers:
9	Current Period Adjustment
10
11
12
13
14
15	Total
16
17	Relinquished During Year:
18	Charges to Account 509	1,437	26,384									1,437	26,384
19	Other:
20	Allowances Used
20.1	Allowances Used
21	Cost of Sales/Transfers:
22
23
24
25
26
27
28	Total
29	Balance-End of Year	1,125	20,170	2,267		2,267		2,267		4,534		12,460	20,170
30
31	Sales:
32	Net Sales Proceeds(Assoc. Co.)
33	Net Sales Proceeds (Other)
34	Gains
35	Losses
	Allowances Withheld (Acct 158.2)
36	Balance-Beginning of Year
37	Add: Withheld by EPA
38	Deduct: Returned by EPA
39	Cost of Sales
40	Balance-End of Year
41
42	Sales
43	Net Sales Proceeds (Assoc. Co.)
44	Net Sales Proceeds (Other)
45	Gains
46	Losses

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: AllowancesIssuedLessWithheldAllowancesNumber

Future years include allowances issued from 2025 through 2026.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

EXTRAORDINARY PROPERTY LOSSES (Account 182.1)
				WRITTEN OFF DURING YEAR
Line No.	DescriptionOfExtraordinaryPropertyLoss Description of Extraordinary Loss [Include in the description the date of Commission Authorization to use Acc 182.1 and period of amortization (mo, yr to mo, yr).] (a)	ExtraordinaryPropertyLossesNotYetRecognized Total Amount of Loss (b)	ExtraordinaryPropertyLossesRecognized Losses Recognized During Year (c)	ExtraordinaryPropertyLossesWrittenOffAccountCharged Account Charged (d)	ExtraordinaryPropertyLossesWrittenOff Amount (e)	ExtraordinaryPropertyLosses Balance at End of Year (f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
20	TOTAL

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

UNRECOVERED PLANT AND REGULATORY STUDY COSTS (182.2)
				WRITTEN OFF DURING YEAR
Line No.	DescriptionOfUnrecoveredPlantAndRegulatoryStudyCosts Description of Unrecovered Plant and Regulatory Study Costs [Include in the description of costs, the date of COmmission Authorization to use Acc 182.2 and period of amortization (mo, yr to mo, yr)] (a)	UnrecoveredPlantAndRegulatoryStudyCostsNotYetRecognized Total Amount of Charges (b)	UnrecoveredPlantAndRegulatoryStudyCostsRecognized Costs Recognized During Year (c)	UnrecoveredPlantAndRegulatoryStudyCostsWrittenOffAccountCharged Account Charged (d)	UnrecoveredPlantAndRegulatoryStudyCostsWrittenOff Amount (e)	UnrecoveredPlantAndRegulatoryStudyCosts Balance at End of Year (f)
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49	TOTAL

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

Transmission Service and Generation Interconnection Study Costs
Report the particulars (details) called for concerning the costs incurred and the reimbursements received for performing transmission service and generator interconnection studies. List each study separately. In column (a) provide the name of the study. In column (b) report the cost incurred to perform the study at the end of period. In column (c) report the account charged with the cost of the study. In column (d) report the amounts received for reimbursement of the study costs at end of period. In column (e) report the account credited with the reimbursement received for performing the study.
Line No.	DescriptionOfStudyPerformed Description (a)	StudyCostsIncurred Costs Incurred During Period (b)	StudyCostsAccountCharged Account Charged (c)	StudyCostsReimbursements Reimbursements Received During the Period (d)	StudyCostsAccountReimbursed Account Credited With Reimbursement (e)
1	Transmission Studies
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20	Total
21	Generation Studies
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39	Total
40	Grand Total

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

OTHER REGULATORY ASSETS (Account 182.3)
Report below the particulars (details) called for concerning other regulatory assets, including rate order docket number, if applicable. Minor items (5% of the Balance in Account 182.3 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes. For Regulatory Assets being amortized, show period of amortization.
				CREDITS
Line No.	DescriptionAndPurposeOfOtherRegulatoryAssets Description and Purpose of Other Regulatory Assets (a)	OtherRegulatoryAssets Balance at Beginning of Current Quarter/Year (b)	IncreaseDecreaseInOtherRegulatoryAssets Debits (c)	OtherRegulatoryAssetsWrittenOffAccountCharged Written off During Quarter/Year Account Charged (d)	OtherRegulatoryAssetsWrittenOffRecovered Written off During the Period Amount (e)	OtherRegulatoryAssets Balance at end of Current Quarter/Year (f)
1	Derivative Instruments and Hedging Activities	5,020,445	1,688,919			6,709,364
2	MISO Financial Transmission Rights Mark-to-Market		402,585			402,585
3	Asset Retirement Obligation - Fossil	7,428,685	453,828			7,882,513
4	Asset Retirement Obligation - Coal	425,824	110,210			536,034
5	Defined Benefit Pension & Other Post Retirement Plans	240,456,058		253, 228.3, 107, 926, 410.1, 411.1	68,271,508	172,184,550
6	Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 130 months beg Oct 2020	2,029,884		926	191,799	1,838,085
7	Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 120 months beg July 2021		12,364,120	926	367,410	11,996,710
8	Deferred Attorney General Litigation Costs MPSC Docket No. 2009-UN-388 Amort 6 years beg April 2020	25,336,744		506, 561.5, 920, 921, 923, 926, 928	4,826,046	20,510,698
9	Deferred Electric Storm Restoration Costs		5,760,571			5,760,571
10	Formula Rate Plan 2021 Settlement MPSC Docket No. 2018-UN-205 Amort 12 months beg June 2021		17,669,553	407.3	10,251,831	7,417,722
11	Electric Deferred Fuel Under-Recovery		121,878,218			121,878,218
12	Energy Efficiency Rider Under-Recovery	2,379,841	9,736,122			12,115,963
13	Restructuring Credit Rider Under-Recovery MPSC Docket No. 2018-UA-39	155,410	274,806			430,216
14	Power Management Rider Under-Recovery MPSC Docket No. 2014-UN-132	6,837,754		407.3	6,837,754
15	Ad Valorem Tax Adjustment Rider MPSC Docket No. 2014-UN-132	27,980,280		408.1	617,165	27,363,115
16	Vegetation Management Rider MPSC Docket No. 2018-UN-205	7,061,164		407.3	6,332,770	728,394
17	Deferred COVID-19 costs MPSC Docket No. 2018-AD-141 - Amort July 2021-June 2022	19,219,538		904, 163, 500, 506, 511, 514, 546, 549, 556, 560, 561.2, 561.5, 566, 568, 569, 573 , 580, 588, 590, 591, 598, 901, 902, 903, 907, 909, 913, 920 921, 923, 930.1, 930.2, 935	4,247,992	14,971,546
18	Choctaw Generating Station Under-Recovery MPSC Docket No. 2018-UN-205 - Amort April 2021-March 2022		1,147,559	407.3	717,224	430,335
19	Income Taxes		25,118,080			25,118,080
20	Formula Rate Plan Revenue Increase MPSC Docket No. 2018-UN-205		19,000,000			19,000,000
44	TOTAL	344,331,627	215,604,571		102,661,499	457,274,699

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

MISCELLANEOUS DEFFERED DEBITS (Account 186)
Report below the particulars (details) called for concerning miscellaneous deferred debits. For any deferred debit being amortized, show period of amortization in column (a) Minor item (1% of the Balance at End of Year for Account 186 or amounts less than $100,000, whichever is less) may be grouped by classes.
				CREDITS
Line No.	Description of Miscellaneous Deferred Debits (a)	Balance at Beginning of Year (b)	Debits (c)	Credits Account Charged (d)	Credits Amount (e)	Balance at End of Year (f)
1	ISES Acquisition Adjustment	356,400		426.5	178,200	178,200
2	Non-Expense Accrued Labor	1,885,170	128,576			2,013,746
3	Section 263A	125,611		930.2	15,701	109,910
4	Mark-to-Market	14,569		930.2	1,325	13,244
47	Miscellaneous Work in Progress
48	Deferred Regulatroy Comm. Expenses (See pages 350 - 351)
49	TOTAL	2,381,750				2,315,100

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

ACCUMULATED DEFERRED INCOME TAXES (Account 190)
Report the information called for below concerning the respondent’s accounting for deferred income taxes. At Other (Specify), include deferrals relating to other income and deductions.
Line No.	DescriptionOfAccumulatedDeferredIncomeTax Description and Location (a)	AccumulatedDeferredIncomeTaxes Balance at Beginning of Year (b)	AccumulatedDeferredIncomeTaxes Balance at End of Year (c)
1	Electric
2	(a) See Footnote	604,138,349	607,243,412
7	Other
8	TOTAL Electric (Enter Total of lines 2 thru 7)	604,138,349	607,243,412
9	Gas
15	Other
16	TOTAL Gas (Enter Total of lines 10 thru 15)
17.1	Other (Specify)
17	Other (Specify)
18	TOTAL (Acct 190) (Total of lines 8, 16 and 17)	604,138,349	607,243,412

Notes

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: DescriptionOfAccumulatedDeferredIncomeTax


	BALANCE AT BEG OF YEAR	BALANCE AT END OF YEAR
Abandonment Loss	$1,425,680	$1,425,680
Intrst/Tax Tax Deficiencies	324,350	324,350
Taxable Unbilled Revenue	2,989,037	2,306,012
Property Insurance Reserve	10,192,222	6,842,571
Capitalized Repairs	514,987	343,363
Injuries & Damages Reserve	1,306,620	1,104,343
Contribution in Aid of Construction	8,486,129	8,597,766
Pension Plan	(25,444,365)	(22,836,428)
Defined Benefit Pension	58,488,326	41,545,899
Supplemental Pension Plan	522,485	583,765
Other Post Employment Benefits	(7,554,867)	(8,530,942)
Deferred Fuel	(1,706,019)	1
Removal Cost	(15,765,717)	(25,244,903)
Accrual of Reserves	—	15,974
Asset Retirement Obligation	1,006	1,006
Litigation Settlement	—	62,375
Accrued Medical Claims	791,730	738,291
Uncollectible Accounts	4,871,921	1,798,671
Def Gain/Basis Step-Up	259,176	215,142
Basis Step-Up	4,414,175	3,209,109
Regulatory Liability	(4,584,563)	(3,461,813)
Partnership Income/Loss	22,979	2,052
Contract Deferred Revenue	26,586	55,866
Lease - Rental Expense	59,445	93,946
Environmental Reserve	103,792	103,792
Incentive Compensation	1,400,984	1,880,868
Long-Term Incentive Compensation	70,734	76,358
Stock Options	11,207	23,748
Restricted Stock Awards	187,065	200,207
Rate Refund	134,231	—
Transition Costs	601,468	300,735
Payroll Tax Accruals	453,393	—
Income tax adjustment	58,149,032	61,994,672
Tax Attribute - NOL/CR Carryforward	6,774,083	2,509,371
ADIT-NOL-SRLY Fed NonCur	356,504,820	280,290,570
ADIT-Tax CR Carryforward	1,278,623	3,322,111
Fed Offset-St Carryover	(22,630,606)	(24,464,775)
ADIT NOL Carryforward	159,465,950	269,786,591
ADIT-Ben-Potnt Disall UTPs Res	1,992,250	2,027,068
TOTAL	$604,138,349	$607,243,412

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

CAPITAL STOCKS (Account 201 and 204)
Report below the particulars (details) called for concerning common and preferred stock at end of year, distinguishing separate series of any general class. Show separate totals for common and preferred stock. If information to meet the stock exchange reporting requirement outlined in column (a) is available from the SEC 10-K Report Form filing, a specific reference to report form (i.e., year and company title) may be reported in column (a) provided the fiscal years for both the 10-K report and this report are compatible. Entries in column (b) should represent the number of shares authorized by the articles of incorporation as amended to end of year. Give details concerning shares of any class and series of stock authorized to be issued by a regulatory commission which have not yet been issued. The identification of each class of preferred stock should show the dividend rate and whether the dividends are cumulative or noncumulative. State in a footnote if any capital stock that has been nominally issued is nominally outstanding at end of year. Give particulars (details) in column (a) of any nominally issued capital stock, reacquired stock, or stock in sinking and other funds which is pledged, stating name of pledgee and purpose of pledge.
Line No.	Class and Series of Stock and Name of Stock Series (a)	Number of Shares Authorized by Charter (b)	Par or Stated Value per Share (c)	Call Price at End of Year (d)	Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Shares (e)	Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Amount (f)	Held by Respondent As Reacquired Stock (Acct 217) Shares (g)	Held by Respondent As Reacquired Stock (Acct 217) Cost (h)	Held by Respondent In Sinking and Other Funds Shares (i)	Held by Respondent In Sinking and Other Funds Amount (j)
1	Common Stock (Account 201)
2
3
4
5	Total
6	Preferred Stock (Account 204)
7
8
9
10	Total
1	Capital Stock (Accounts 201 and 204) - Data Conversion
2
3
4
5	Total

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

2022-04-15

Year/Period of Report

End of:

2021

/

Q4

Other Paid-in Capital
1. Report below the balance at the end of the year and the information specified below for the respective other paid-in capital accounts. Provide a subheading for each account and show a total for the account, as well as a total of all accounts for reconciliation with the balance sheet, page 112. Explain changes made in any account during the year and give the accounting entries effecting such change. Donations Received from Stockholders (Account 208) - State amount and briefly explain the origin and purpose of each donation. Reduction in Par or Stated Value of Capital Stock (Account 209) - State amount and briefly explain the capital changes that gave rise to amounts reported under this caption including identification with the class and series of stock to which related. Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210) - Report balance at beginning of year, credits, debits, and balance at end of year with a designation of the nature of each credit and debit identified by the class and series of stock to which related. Miscellaneous Paid-In Capital (Account 211) - Classify amounts included in this account according to captions that, together with brief explanations, disclose the general nature of the transactions that gave rise to the reported amounts.
Line No.	Item (a)	Amount (b)
1	DonationsReceivedFromStockholdersAbstract Donations Received from Stockholders (Account 208)
2	DonationsReceivedFromStockholders Beginning Balance Amount
3.1	IncreasesDecreasesFromSalesOfDonationsReceivedFromStockholders Increases (Decreases) from Sales of Donations Received from Stockholders
4	DonationsReceivedFromStockholders Ending Balance Amount
5	ReductionInParOrStatedValueOfCapitalStockAbstract Reduction in Par or Stated Value of Capital Stock (Account 209)
6	ReductionInParOrStatedValueOfCapitalStock Beginning Balance Amount
7.1	IncreasesDecreasesDueToReductionsInParOrStatedValueOfCapitalStock Increases (Decreases) Due to Reductions in Par or Stated Value of Capital Stock
8	ReductionInParOrStatedValueOfCapitalStock Ending Balance Amount
9	GainOrResaleOrCancellationOfReacquiredCapitalStockAbstract Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210)
10	GainOnResaleOrCancellationOfReacquiredCapitalStock Beginning Balance Amount
11.1	IncreasesDecreasesFromGainOrResaleOrCancellationOfReacquiredCapitalStock Increases (Decreases) from Gain or Resale or Cancellation of Reacquired Capital Stock
12	GainOnResaleOrCancellationOfReacquiredCapitalStock Ending Balance Amount
13	MiscellaneousPaidInCapitalAbstract Miscellaneous Paid-In Capital (Account 211)
14	MiscellaneousPaidInCapital Beginning Balance Amount	329,266,361
15.1	IncreasesDecreasesDueToMiscellaneousPaidInCapital Increases (Decreases) Due to Miscellaneous Paid-In Capital
16	MiscellaneousPaidInCapital Ending Balance Amount	329,266,361
17	OtherPaidInCapitalAbstract Historical Data - Other Paid in Capital
18	OtherPaidInCapitalDetail Beginning Balance Amount
19.1	IncreasesDecreasesInOtherPaidInCapital Increases (Decreases) in Other Paid-In Capital
20	OtherPaidInCapitalDetail Ending Balance Amount
40	OtherPaidInCapital Total	329,266,361

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

CAPITAL STOCK EXPENSE (Account 214)
Report the balance at end of the year of discount on capital stock for each class and series of capital stock. If any change occurred during the year in the balance in respect to any class or series of stock, attach a statement giving particulars (details) of the change. State the reason for any charge-off of capital stock expense and specify the account charged.
Line No.	NameOfClassAndSeriesOfStock Class and Series of Stock (a)	CapitalStockExpense Balance at End of Year (b)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22	TOTAL

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

LONG-TERM DEBT (Account 221, 222, 223 and 224)
Report by Balance Sheet Account the details concerning long-term debt included in Accounts 221, Bonds, 222, Reacquired Bonds, 223, Advances from Associated Companies, and 224, Other Long-Term Debt. For bonds assumed by the respondent, include in column (a) the name of the issuing company as well as a description of the bonds, and in column (b) include the related account number. For Advances from Associated Companies, report separately advances on notes and advances on open accounts. Designate demand notes as such. Include in column (a) names of associated companies from which advances were received, and in column (b) include the related account number. For receivers' certificates, show in column (a) the name of the court and date of court order under which such certificates were issued, and in column (b) include the related account number. In a supplemental statement, give explanatory details for Accounts 223 and 224 of net changes during the year. With respect to long-term advances, show for each company: (a)principal advanced during year (b) interest added to principal amount, and (c) principal repaid during year. Give Commission authorization numbers and dates. If the respondent has pledged any of its long-term debt securities, give particulars (details) in a footnote, including name of the pledgee and purpose of the pledge. If the respondent has any long-term securities that have been nominally issued and are nominally outstanding at end of year, describe such securities in a footnote. If interest expense was incurred during the year on any obligations retired or reacquired before end of year, include such interest expense in column (m). Explain in a footnote any difference between the total of column (m) and the total Account 427, Interest on Long-Term Debt and Account 430, Interest on Debt to Associated Companies. Give details concerning any long-term debt authorized by a regulatory commission but not yet issued.
Line No.	ClassAndSeriesOfObligationCouponRateDescription Class and Series of Obligation, Coupon Rate (For new issue, give commission Authorization numbers and dates) (a)	RelatedAccountNumber Related Account Number (b)	Principal Amount of Debt Issued (c)	LongTermDebtIssuanceExpensePremiumOrDiscount Total Expense, Premium or Discount (d)	LongTermDebtIssuanceExpenses Total Expense (e)	LongTermDebtPremium Total Premium (f)	LongTermDebtDiscount Total Discount (g)	NominalDateOfIssue Nominal Date of Issue (h)	DateOfMaturity Date of Maturity (i)	AmortizationPeriodStartDate AMORTIZATION PERIOD Date From (j)	AmortizationPeriodEndDate AMORTIZATION PERIOD Date To (k)	Outstanding (Total amount outstanding without reduction for amounts held by respondent) (l)	Interest for Year Amount (m)
1	Bonds (Account 221)
2	3.1% Series	221	250,000,000		1,992,167		985,000	12/11/2012	07/01/2023	12/11/2012	07/01/2023	250,000,000	7,750,000
3	3.75% Series	221	100,000,000		954,738		30,000	03/21/2014	07/01/2024	03/21/2014	07/01/2024	100,000,000	3,750,000
4	2.85% Series	221	375,000,000		2,878,733		120,000	05/13/2016	06/01/2028	05/13/2016	06/01/2028	375,000,000	10,687,500
5	4.9% Series	221	260,000,000		8,107,064			09/15/2016	10/01/2066	09/15/2016	10/01/2066	260,000,000	12,740,000
6	3.25% Series	221	150,000,000		1,362,173		511,500	11/14/2017	12/01/2027	11/14/2017	12/01/2027	150,000,000	4,875,000
7	4.52% Series	221	55,000,000		511,787			12/12/2018	12/01/2038	12/12/2018	12/01/2038	55,000,000	2,486,000
8	3.85% Series 1	221	300,000,000		3,171,620		3,891,000	06/05/2019	06/01/2049	06/05/2019	06/01/2049	300,000,000	11,550,000
9	3.85% Series 2	221	135,000,000		1,395,028	10,813,500		11/19/2019	06/01/2049	11/19/2019	06/01/2049	135,000,000	5,197,500
10	3.5% Series 1	221	170,000,000		2,166,734		2,410,600	05/22/2020	06/01/2051	05/22/2020	06/01/2051	170,000,000	5,950,000
11	3.5% Series 2	221	200,000,000		2,150,279	2,754,000		03/12/2021	06/01/2051	03/12/2021	06/01/2051	200,000,000	5,619,444
12	2.55% Series	221	200,000,000		1,748,183		516,000	11/16/2021	12/01/2033	11/16/2021	12/01/2033	200,000,000	637,500
13	Subtotal		2,195,000,000		26,438,506	13,567,500	8,464,100					2,195,000,000	71,242,944
14	Reacquired Bonds (Account 222)
15
16
17
18	Subtotal
19	Advances from Associated Companies (Account 223)
20
21
22
23	Subtotal
24	Other Long Term Debt (Account 224)
25
26
27
28	Subtotal
33	TOTAL		2,195,000,000									2,195,000,000	(a) 71,242,944

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: InterestExpenseOnLongTermDebtIssued

Total interest for Accounts 221 and 224 is recorded in Account 427, as shown on page 117, line 62.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXES
Report the reconciliation of reported net income for the year with taxable income used in computing Federal income tax accruals and show computation of such tax accruals. Include in the reconciliation, as far as practicable, the same detail as furnished on Schedule M-1 of the tax return for the year. Submit a reconciliation even though there is no taxable income for the year. Indicate clearly the nature of each reconciling amount. If the utility is a member of a group which files a consolidated Federal tax return, reconcile reported net income with taxable net income as if a separate return were to be field, indicating, however, intercompany amounts to be eliminated in such a consolidated return. State names of group member, tax assigned to each group member, and basis of allocation, assignment, or sharing of the consolidated tax among the group members. A substitute page, designed to meet a particular need of a company, may be used as Long as the data is consistent and meets the requirements of the above instructions. For electronic reporting purposes complete Line 27 and provide the substitute Page in the context of a footnote.
Line No.	Particulars (Details) (a)	Amount (b)
1	Net Income for the Year (Page 117)	166,834,143
2	Reconciling Items for the Year
3
4	Taxable Income Not Reported on Books
5	(a) See Footnote Detail	8,143,995
9	Deductions Recorded on Books Not Deducted for Return
10	(b) See Footnote Detail	25,213,726
14	Income Recorded on Books Not Included in Return
15	(c) See Footnote Detail	4,793,511
19	Deductions on Return Not Charged Against Book Income
20	(d) See Footnote Detail	337,605,822
21	(e) Other Reconciling Items - See footnote detail	192,634,921
27	Federal Tax Net Income
28	Show Computation of Tax:
29	Normal and Surtax @ 21%
30	(f) Estimated Consolidated Income Tax Allocated - See Footnote Detail - applicable for 1/1/21 - 12/31/21

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: TaxableIncomeNotReportedOnBooksDescription


Taxable Income Not Recorded on Books:
Avoided Cost - Tax Interest			$1,221,118
Contributions in Aid of Construction			4,904,814
Deferred Contract Revenue			255,636
Obligation for Customer Credits			4,500,000
Unbilled Revenue			(2,737,573)
Total			$8,143,995

(b) Concept: DeductionsRecordedOnBooksNotDeductedForReturnDescription


Deductions Recorded on Books Not Deducted for Return:
Accrual of Reserves			($15,739,364)
Deferred Compensation and Benefits			2,048,858
Meals and Entertainment			50,142
Penalties			(9,040)
Political Expenses			753,310
Reserve for Uncollectible Accounts			(12,317,632)
Total			($25,213,726)

(c) Concept: IncomeRecordedOnBooksNotIncludedInReturnDescription


Income Recorded on Books Not Included in Return:
Allowance for Funds Used During Construction			$4,793,511

(d) Concept: DeductionsOnReturnNotChargedAgainstBookIncomeDescription


Deductions on Return Not Charged Against Book Income:
Amortization of Other Assets			$28,270,002
Amortization of Regulatory Assets			(4,247,992)
Bond Reacquisition Loss			(1,356,973)
Decommissioning Costs			(30,249)
Deferred Compensation & Benefits			52,266
Deferred Fuel			115,040,463
Depreciation of Plant Assets			188,545,160
Service Company Billings			1,815,870
Pension and OPEB			(18,185,116)
Prepaid Expenses			695,049
Research and Development Costs			(7,535,194)
Software Costs			5,420,019
UOP Repairs			29,122,517
Total			$337,605,822

(e) Concept: DeductionsOnReturnNotChargedAgainstBookIncomeDescription


Reconciling Items for the Year:
Net Operating Loss			$147,311,997
Federal Income Tax Accrual - Prior year			(5,868,119)
Investment Tax Credit			1,836,307
FIN 48 taxes			2,087,553
Provision for Deferred Income Tax			58,773,258
State Income Tax Accrual - Prior Year			(11,506,075)
Total			$192,634,921

(f) Concept: ComputationOfTaxDescription

The Respondent intends to join in the filing of a consolidated Federal Income Tax Return by Entergy Corporation and Subsidiary Companies for the year ended 2021. The estimated consolidated tax allocable under Entergy and Subsidiary Companies Intercompany Income Tax Allocation Agreement based on the provisions of Securities and Exchange Commission Rule 45(c) follows:


FOOTNOTE DATA


Entergy Utility Property, Inc.			$162,000
Entergy Utility Affiliates, LLC			(15,000)
Entergy Utility Assets Holdings, Inc.			904,000
Entergy Utility Group, Inc.			(21,000)
System Energy Resources, Inc.			30,734,000
Entergy Operations, Inc.			(97,000)
Entergy Corporation			(36,765,000)
Entergy Solutions LLC			(1,000)
Entergy Nuclear New York Investment Company, LLC			1,317,000
Entergy Nuclear Holding Company #3, LLC			(3,543,000)
Entergy Assets Management Company, LLC			(3,834,000)
Entergy Northeast Holdings, LLC			(18,320,000)
Entergy Power Marketing Holding II, Inc.			(108,000)
Entergy Nuclear Power Marketing, LLC			7,248,000
Entergy Nuclear, Inc.			(442,000)
Entergy Nuclear Holding Company #1			(5,454,000)
Entergy Nuclear Operations, Inc.			(13,904,000)
Entergy Power Holdings, Inc.			2,991,000
Entergy TransCo HoldCo, LLC			(7,000)
EAM Nelson Holding, LLC			332,000
Entergy Nighthawk GP, LLC			876,000
Entergy Power Investment Holding, Inc.			1,962,000
Entergy Mississippi Turbine Company			(16,000)
Entergy Nuclear Holding Company #2			221,000
Entergy Power, LLC			(149,000)
Entergy Enterprises, Inc.			(31,000)
Entergy Power Gas Operations, LLC			9,627,000
Entergy Power Marketing Holding I, Inc.			(3,887,000)
Entergy Power Operations U.S., Inc.			166,000
Entergy Nuclear Palisades, LLC			(9,752,000)
EK Holding III, LLC			(2,000)
EWO Marketing, LLC			(40,000)
Entergy Global, LLC			(77,000)
Entergy Ventures, Inc.			(80,000)
EUP Holdings, LLC			259,000
Entergy Technology Company			(3,000)
Warren Power, LLC			(1,000)
Entergy TransCo Texas, LLC			(11,000)
Entergy Services Holding, Inc. (Supplemental Information below)			75,187,000
Entergy Asset Management, Inc.			4,156,000
Entergy Investments Holding Company, Inc.			(3,000)
EWO Wind II, LLC			(19,000)
Entergy Nuclear Indian Point 2, LLC			(11,037,000)
Entergy Nuclear Indian Point 3, LLC			(12,579,000)
Entergy Finance Company, LLC			51,137,000
Entergy New Orleans, LLC			(6,566,000)
Entergy Utility Holding Company, LLC (Supplemental Information below)			(60,440,000)
Morpheus One Holdings, LLC			(75,000)
Total			$—


FOOTNOTE DATA


Supplemental Information -Entergy Utility Holding Company, LLC
Entergy Louisiana, LLC			($28,329,000)
Entergy Arkansas, LLC			(21,083,000.00)
Entergy Mississippi, LLC			(9,614,000.00)
Entergy Utility Holding Company, LLC			(1,414,000.00)
Total			($60,440,000)

Supplemental Information -Entergy Services Holdings, Inc
Entergy Services Holdings, Inc.			$41,991,000
Entergy Services, LLC			29,168,000.00
Entergy Account Services, LLC			4,028,000.00
Total			$75,187,000

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

TAXES ACCRUED, PREPAID AND CHARGES DURING YEAR
Give particulars (details) of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts during the year. Do not include gasoline and other sales taxes which have been charged to the accounts to which the taxed material was charged. If the actual, or estimated amounts of such taxes are known, show the amounts in a footnote and designate whether estimated or actual amounts. Include on this page, taxes paid during the year and charged direct to final accounts, (not charged to prepaid or accrued taxes.) Enter the amounts in both columns (g) and (h). The balancing of this page is not affected by the inclusion of these taxes. Include in column (g) taxes charged during the year, taxes charged to operations and other accounts through (a) accruals credited to taxes accrued, (b)amounts credited to proportions of prepaid taxes chargeable to current year, and (c) taxes paid and charged direct to operations or accounts other than accrued and prepaid tax accounts. List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can readily be ascertained. If any tax (exclude Federal and State income taxes) covers more than one year, show the required information separately for each tax year, identifying the year in column (d). Enter all adjustments of the accrued and prepaid tax accounts in column (i) and explain each adjustment in a foot- note. Designate debit adjustments by parentheses. Do not include on this page entries with respect to deferred income taxes or taxes collected through payroll deductions or otherwise pending transmittal of such taxes to the taxing authority. Report in columns (l) through (o) how the taxes were distributed. Report in column (o) only the amounts charged to Accounts 408.1 and 409.1 pertaining to electric operations. Report in column (l) the amounts charged to Accounts 408.1 and 409.1 pertaining to other utility departments and amounts charged to Accounts 408.2 and 409.2. Also shown in column (o) the taxes charged to utility plant or other balance sheet accounts. For any tax apportioned to more than one utility department or account, state in a footnote the basis (necessity) of apportioning such tax.
					BALANCE AT BEGINNING OF YEAR					BALANCE AT END OF YEAR		DISTRIBUTION OF TAXES CHARGED
Line No.	DescriptionOfTaxesAccruedPrepaidAndCharged Kind of Tax (See Instruction 5) (a)	TypeOfTax Type of Tax (b)	TaxJurisdiction State (c)	TaxYear Tax Year (d)	TaxesAccrued Taxes Accrued (Account 236) (e)	PrepaidTaxes Prepaid Taxes (Include in Account 165) (f)	TaxesCharged Taxes Charged During Year (g)	TaxesPaid Taxes Paid During Year (h)	TaxAdjustments Adjustments (i)	TaxesAccrued Taxes Accrued (Account 236) (j)	PrepaidTaxes Prepaid Taxes (Included in Account 165) (k)	TaxesAccruedPrepaidAndCharged Electric (Account 408.1, 409.1) (l)	IncomeTaxesExtraordinaryItems Extraordinary Items (Account 409.3) (m)	AdjustmentsToRetainedEarnings Adjustment to Ret. Earnings (Account 439) (n)	TaxesIncurredOther Other (o)
1	Federal Income Tax	Federal Tax			46,088,400	0	5,675,141	8,257,000		48,670,259		4,115,772			1,559,369
2	FICA	Federal Tax			2,828,961	0	8,166,691	8,355,114		2,640,538		3,040,452			5,126,239
3	Federal Uemployment Tax	Federal Tax			7,942	0	34,872	35,164		8,234		16,695			18,177
4	Federal Excise Tax	Federal Tax			0	0	18,575	18,575		0	0	18,575			0
5	Subtotal Federal Tax				48,909,419	0	2,544,997	151,853	0	51,302,563	0	1,040,050	0	0	3,585,047
6	State Income Tax	State Tax			1,356,115	0	11,662,483	11,415,014		1,108,646		11,271,663			390,820
7					0	0				0					0
8	Subtotal State Tax				1,356,115	0	11,662,483	11,415,014	0	1,108,646	0	11,271,663	0	0	390,820
9	Franchise - City	Local Tax			3,998,836	0	14,762,826	14,566,890		4,194,772		14,762,826			0
10	Subtotal Local Tax				3,998,836	0	14,762,826	14,566,890	0	4,194,772	0	14,762,826	0	0	0
11	Privilege License	Other Taxes			0	60,880	77,369	79,544		0	63,055	77,369			0
12	Regulatory Commission	Other Taxes			0	0	993,657	993,657		0	0	1,987,315			993,658
13	Subtotal Other Tax				0	60,880	1,071,026	1,073,201	0	0	63,055	2,064,684	0	0	993,658
14	Subtotal Property Tax				0	0	0	0	0	0	0	0	0	0	0
15	Subtotal Real Estate Tax				0	0	0	0	0	0	0	0	0	0	0
16	State Unemployment Tax	Unemployment Tax			91,967	0	35,913	37,087		90,793		16,483			19,430
17	Subtotal Unemployment Tax				91,967	0	35,913	37,087	0	90,793	0	16,483	0	0	19,430
18	State Use Tax	Sales And Use Tax			634,179	0	7,620,159	7,197,505		1,056,833		0			7,620,159
19	Subtotal Sales And Use Tax				634,179	0	7,620,159	7,197,505	0	1,056,833	0	0	0	0	7,620,159
20	Entergy Services, LLC	Income Tax			0	0				0		1,550,983			1,550,983
21	Subtotal Income Tax				0	0	0	0	0	0	0	1,550,983	0	0	1,550,983
22	State Excise Tax	Excise Tax			0	0	13,680	13,680		0		13,680			0
23	Subtotal Excise Tax				0	0	13,680	13,680	0	0	0	13,680	0	0	0
24	Subtotal Fuel Tax				0	0	0	0	0	0	0	0	0	0	0
25	Subtotal Federal Insurance Tax				0	0	0	0	0	0	0	0	0	0	0
26	Corporate Franchise Tax-MS	Franchise Tax			0	187,158	4,715,288	5,587,158		0	684,712	4,377,788			337,500
27	Corporate Franchise Tax-AR	Franchise Tax			0	17	0	0		0	17	150			150
28	Subtotal Franchise Tax				0	187,141	4,715,288	5,587,158	0	0	684,729	4,377,938	0	0	337,350
29	Non Income Tax	Miscellaneous Other Tax			1,300,000	0	0	0		1,300,000		0			0
30	Subtotal Miscellaneous Other Tax				1,300,000	0	0	0	0	1,300,000	0	0	0	0	0
31	Subtotal Other Federal Tax				0	0	0	0	0	0	0	0	0	0	0
32	Receipts & Sales	Other State Tax			1,563	0	21,392	20,863		2,092		21,392			0
33	Subtotal Other State Tax				1,563	0	21,392	20,863	0	2,092	0	21,392	0	0	0
34	Subtotal Other Property Tax				0	0	0	0	0	0	0	0	0	0	0
35	Subtotal Other Use Tax				0	0	0	0	0	0	0	0	0	0	0
36	Ad Valorem Tax - MS	Other Ad Valorem Tax			99,912,000	0	86,201,818	87,545,818		98,568,000		83,358,798			2,843,020
37	Ad Valorem Tax - AR	Other Ad Valorem Tax			1,218,937	0	1,230,543	1,221,480		1,228,000		1,230,543			0
38	Subtotal Other Advalorem Tax				101,130,937	0	87,432,361	88,767,298	0	99,796,000	0	84,589,341	0	0	2,843,020
39	Subtotal Other License And Fees Tax				0	0	0	0	0	0	0	0	0	0	0
40	Subtotal Payroll Tax				0	0	0	0	0	0	0	0	0	0	0
41	Subtotal Advalorem Tax				0	0	0	0	0	0	0	0	0	0	0
42	Entergy Services, LLC	Other Allocated Tax			0	0				0		2,789,492			2,789,492
43	Subtotal Other Allocated Tax				0	0	0	0	0	0	0	2,789,492	0	0	2,789,492
44	Subtotal Severance Tax				0	0	0	0	0	0	0	0	0	0	0
45	Subtotal Penalty Tax				0	0	0	0	0	0	0	0	0	0	0
46	Subtotal Other Taxes And Fees				0	0	0	0	0	0	0	0	0	0	0
40	TOTAL				157,423,016	126,261	106,555,159	106,000,521	0	158,851,699	747,784	97,875,106	0	0	8,680,053

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

ACCUMULATED DEFERRED INVESTMENT TAX CREDITS (Account 255)
Report below information applicable to Account 255. Where appropriate, segregate the balances and transactions by utility and nonutility operations. Explain by footnote any correction adjustments to the account balance shown in column (g). Include in column (i) the average period over which the tax credits are amortized.
			Deferred for Year		Allocations to Current Year's Income
Line No.	Account Subdivisions (a)	Balance at Beginning of Year (b)	Account No. (c)	Amount (d)	Account No. (e)	Amount (f)	Adjustments (g)	Balance at End of Year (h)	Average Period of Allocation to Income (i)	ADJUSTMENT EXPLANATION (j)
1	Electric Utility
2	3%
3	4%
4	7%
5	10%	4,826,274			411.4	223,478		4,602,796	(a) 20.5 years
8	TOTAL Electric (Enter Total of lines 2 thru 7)	4,826,274				223,478		4,602,796
9	Other (List separately and show 3%, 4%, 7%, 10% and TOTAL)
10										`
11	Mississippi ITC	4,236,025	411.4	2,073,959				6,309,984
47	OTHER TOTAL	4,236,025		2,073,959				6,309,984
48	GRAND TOTAL	9,062,299		2,073,959		223,478		10,912,780

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: AccumulatedDeferredInvestmentTaxCreditsAveragePeriodOfAllocationToIncome

Average lives are based on estimated composite useful lives of the properties and are subject to reconsideration each year.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

OTHER DEFERRED CREDITS (Account 253)
Report below the particulars (details) called for concerning other deferred credits. For any deferred credit being amortized, show the period of amortization. Minor items (5% of the Balance End of Year for Account 253 or amounts less than $100,000, whichever is greater) may be grouped by classes.
			DEBITS
Line No.	Description and Other Deferred Credits (a)	Balance at Beginning of Year (b)	Contra Account (c)	Amount (d)	Credits (e)	Balance at End of Year (f)
1	Long-Term Incentive Plan	283,504	131	135,984	158,524	306,044
2	Non-Qualified Pension funded status	3,670,778	131	210,576	58,071	3,518,273
3	Qualified Pension funded status	138,715,084	107,182.3,131,926	46,280,897		92,434,187
4	Choctaw purchase - escrow funds	15,700,000	131	15,700,000
5	Deferred Payroll Employer Tax	1,817,208	131	1,817,208
6	Employment Litigation				250,000	250,000
7	Deferred rebate	6,209	131	7,140		931
8	Other				9,430	9,430
47	TOTAL	160,192,783		64,151,805	476,025	96,517,003

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

ACCUMULATED DEFERRED INCOME TAXES - ACCELERATED AMORTIZATION PROPERTY (Account 281)

Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to amortizable property.
For other (Specify),include deferrals relating to other income and deductions.
Use footnotes as required.

CHANGES DURING YEAR

ADJUSTMENTS

Debits

Credits

Line No.

Account

(a)

Balance at Beginning of Year

(b)

Amounts Debited to Account 410.1

(c)

Amounts Credited to Account 411.1

(d)

Amounts Debited to Account 410.2

(e)

Amounts Credited to Account 411.2

(f)

Account Credited

(g)

Amount

(h)

Account Debited

(i)

Amount

(j)

Balance at End of Year

(k)

1

Accelerated Amortization (Account 281)

2

Electric

3

Defense Facilities

4

Pollution Control Facilities

5

Other

5.1

Other (provide details in footnote):

8

TOTAL Electric (Enter Total of lines 3 thru 7)

9

Gas

10

Defense Facilities

11

Pollution Control Facilities

12

Other

12.1

Other (provide details in footnote):

15

TOTAL Gas (Enter Total of lines 10 thru 14)

16

Other

16.1

Other

16.2

Other

17

TOTAL (Acct 281) (Total of 8, 15 and 16)

18

Classification of TOTAL

19

Federal Income Tax

20

State Income Tax

21

Local Income Tax

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

ACCUMULATED DEFERRED INCOME TAXES - OTHER PROPERTY (Account 282)
Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to property not subject to accelerated amortization. For other (Specify),include deferrals relating to other income and deductions. Use footnotes as required.
			CHANGES DURING YEAR				ADJUSTMENTS
							Debits		Credits
Line No.	Account (a)	Balance at Beginning of Year (b)	Amounts Debited to Account 410.1 (c)	Amounts Credited to Account 411.1 (d)	Amounts Debited to Account 410.2 (e)	Amounts Credited to Account 411.2 (f)	Account Credited (g)	Amount (h)	Account Debited (i)	Amount (j)	Balance at End of Year (k)
1	Account 282
2	Electric	661,156,573	83,561,892	44,332,821					182.3/254	9,133,854	709,519,498
3	Gas
4	Other (Specify)
5	Total (Total of lines 2 thru 4)	661,156,573	83,561,892	44,332,821						9,133,854	709,519,498
6
7
8
9	TOTAL Account 282 (Total of Lines 5 thru 8)	661,156,573	83,561,892	44,332,821						9,133,854	709,519,498
10	Classification of TOTAL
11	Federal Income Tax	547,502,132	63,640,332	36,889,441					182.3/254	8,963,105	583,216,128
12	State Income Tax	113,654,441	19,921,560	7,443,380					182.3/254	170,749	126,303,370
13	Local Income Tax

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

ACCUMULATED DEFERRED INCOME TAXES - OTHER (Account 283)
Report the information called for below concerning the respondent's accounting for deferred income taxes relating to amounts recorded in Account 283. For other (Specify),include deferrals relating to other income and deductions. Provide in the space below explanations for Page 276. Include amounts relating to insignificant items listed under Other. Use footnotes as required.
			CHANGES DURING YEAR				ADJUSTMENTS
							Debits		Credits
Line No.	Account (a)	Balance at Beginning of Year (b)	Amounts Debited to Account 410.1 (c)	Amounts Credited to Account 411.1 (d)	Amounts Debited to Account 410.2 (e)	Amounts Credited to Account 411.2 (f)	Account Credited (g)	Amount (h)	Account Debited (i)	Amount (j)	Balance at End of Year (k)
1	Account 283
2	Electric
3	(a) See Footnote Detail	538,416,707	55,710,401	20,609,413			190	16,942,436	182.3/254	6,266,969	562,842,228
9	TOTAL Electric (Total of lines 3 thru 8)	538,416,707	55,710,401	20,609,413				16,942,436		6,266,969	562,842,228
10	Gas
11
12
13
14
15
16
17	TOTAL Gas (Total of lines 11 thru 16)
18	TOTAL Other
19	TOTAL (Acct 283) (Enter Total of lines 9, 17 and 18)	538,416,707	55,710,401	20,609,413				16,942,436		6,266,969	562,842,228
20	Classification of TOTAL
21	Federal Income Tax	430,717,935	45,139,680	17,072,959			190	13,547,160	182.3/254	5,011,065	450,248,561
22	State Income Tax	107,698,772	10,570,721	3,536,454			190	3,395,276	182.3/254	1,255,904	112,593,667
23	Local Income Tax
NOTES

FOOTNOTE DATA

(a) Concept: DescriptionOfAccumulatedDeferredIncomeTaxOther


	CHANGES DURING YEAR
	BALANCE AT BEGINNING OF YEAR	AMOUNTS DEBITED TO ACCT. 410.1	AMOUNTS CREDITED TO ACCT. 411.1	AMOUNTS DEBITED TO ACCT. 410.2	AMOUNTS CREDITED TO ACCT. 411.2
Deferred Fuel	($1)	$31,688,337	$1,279,721	$—	$—
Reg Asset Covid 19	4,795,275	2,034,855	3,094,729	—	—
Reg Asset-Securitization	15,731,877	15,733,576	8,635,749	—	—
Minimum Pension Liability	58,488,318	—	—	—	—
Bond Reacquisition Loss	3,372,428	14,248	352,813	—	—
Section 475 Adj	453,390,322	34,815	862,078	—	—
Distribution Maintenance	(3,705)	3,861	156	—	—
Capitalized Costs	2,071,648	11,276	279,227	—	—
Misc Cap Costs	133,382	3,742	92,664	—	—
Prepaid Expenses	437,143	1,048,678	875,263	—	—
Decon & Decomm Fund	—	5,137,013	5,137,013	—	—
Income Tax Adjustment	20	—	—	—	—
TOTAL	$538,416,707	$55,710,401	$20,609,413	$—	$—


	ADJUSTMENTS
	DEBITS		CREDITS
	ACCOUNT CREDITED	AMOUNT	ACCOUNT DEBITED	AMOUNT	BALANCE AT END OF YEAR
Deferred Fuel		$—		$—	$30,408,615
Reg Asset Covid 19		—		—	3,735,401
Reg Asset-Securitization		—		—	22,829,704
Minimum Pension Liability	190	16,942,436		—	41,545,882
Bond Reacquisition Loss		—		—	3,033,863
Section 475 Adj		—		—	452,563,059
Distribution Maintenance		—		—	—
Capitalized Costs		—		—	1,803,697
Misc Cap Costs		—		—	44,460
Prepaid Expenses		—		—	610,558
Decon & Decomm Fund		—		—	—
Income Tax Adjustment		—	182.3/254	6,266,969	6,266,989
TOTAL		$16,942,436		$6,266,969	$562,842,228

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

OTHER REGULATORY LIABILITIES (Account 254)
Report below the particulars (details) called for concerning other regulatory liabilities, including rate order docket number, if applicable. Minor items (5% of the Balance in Account 254 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes. For Regulatory Liabilities being amortized, show period of amortization.
			DEBITS
Line No.	Description and Purpose of Other Regulatory Liabilities (a)	Balance at Beginning of Current Quarter/Year (b)	Account Credited (c)	Amount (d)	Credits (e)	Balance at End of Current Quarter/Year (f)
1	Income Taxes	223,999,951	190, 282, 283	11,432,221	24,995,126	237,562,856
2	MISO Financial Transmission Rights Mark-to-Market	55,303	175	55,303
3	Grand Gulf Over-Recovery MPSC Docket No. 1984-UN-4620	1,041,956			14,072,097	15,114,053
4	Unit Power Cost Recovery Rider Over-Recovery MPSC Docket No. 2014-UN-132	10,018,905	407.4	2,845,755		7,173,150
5	MISO Rider Over-Recovery MPSC Docket No. 2014-UN-132	3,311,012			1,456,571	4,767,583
6	Power Management Rider Over-Recovery MPSC Docket No. 2014-UN-132				20,822,563	20,822,563
7	Choctaw Generating Station Over-Recovery - MPSC Docket No. 2018-UN-205	538,000	407.4	538,000
8	Grid Modernization Rider Over-Recovery MPSC Docket No. 2017-UN-198	863,116			572,358	1,435,474
9	Electric Deferred Fuel Over-Recovery	14,691,277	557	14,691,277
41	TOTAL	254,519,520		29,562,556	61,918,715	286,875,679

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

Electric Operating Revenues
The following instructions generally apply to the annual version of these pages. Do not report quarterly data in columns (c), (e), (f), and (g). Unbilled revenues and MWH related to unbilled revenues need not be reported separately as required in the annual version of these pages. Report below operating revenues for each prescribed account, and manufactured gas revenues in total. Report number of customers, columns (f) and (g), on the basis of meters, in addition to the number of flat rate accounts; except that where separate meter readings are added for billing purposes, one customer should be counted for each group of meters added. The average number of customers means the average of twelve figures at the close of each month. If increases or decreases from previous period (columns (c),(e), and (g)), are not derived from previously reported figures, explain any inconsistencies in a footnote. Disclose amounts of $250,000 or greater in a footnote for accounts 451, 456, and 457.2. Commercial and industrial Sales, Account 442, may be classified according to the basis of classification (Small or Commercial, and Large or Industrial) regularly used by the respondent if such basis of classification is not generally greater than 1000 Kw of demand. (See Account 442 of the Uniform System of Accounts. Explain basis of classification in a footnote.) See page 108, Important Changes During Period, for important new territory added and important rate increase or decreases. For Lines 2,4,5,and 6, see Page 304 for amounts relating to unbilled revenue by accounts. Include unmetered sales. Provide details of such Sales in a footnote.
Line No.	Title of Account (a)	Operating Revenues Year to Date Quarterly/Annual (b)	Operating Revenues Previous year (no Quarterly) (c)	MEGAWATT HOURS SOLD Year to Date Quarterly/Annual (d)	MEGAWATT HOURS SOLD Amount Previous year (no Quarterly) (e)	AVG.NO. CUSTOMERS PER MONTH Current Year (no Quarterly) (f)	AVG.NO. CUSTOMERS PER MONTH Previous Year (no Quarterly) (g)
1	SalesOfElectricityHeadingAbstract Sales of Electricity
2	ResidentialSalesAbstract (440) Residential Sales	578,258,495	523,378,532	5,568,055	5,378,310	383,468	379,705
3	CommercialAndIndustrialSalesAbstract (442) Commercial and Industrial Sales
4	CommercialSalesAbstract Small (or Comm.) (See Instr. 4)	(a) 439,949,537	(d) 395,875,123	4,468,879	4,283,143	66,343	65,003
5	IndustrialSalesAbstract Large (or Ind.) (See Instr. 4)	150,697,534	145,100,256	2,297,663	2,342,917	4,006	3,620
6	PublicStreetAndHighwayLightingAbstract (444) Public Street and Highway Lighting	15,770,896	14,895,516	77,286	79,387	429	432
7	OtherSalesToPublicAuthoritiesAbstract (445) Other Sales to Public Authorities	30,476,742	27,059,979	333,052	318,116	4,741	4,737
8	SalesToRailroadsAndRailwaysAbstract (446) Sales to Railroads and Railways
9	InterdepartmentalSalesAbstract (448) Interdepartmental Sales
10	SalesToUltimateConsumersAbstract TOTAL Sales to Ultimate Consumers	1,215,153,204	1,106,309,406	12,744,935	12,401,873	458,987	453,497
11	SalesForResaleAbstract (447) Sales for Resale	124,631,972	77,530,332	4,363,569	4,316,175
12	SalesOfElectricityAbstract TOTAL Sales of Electricity	1,339,785,176	1,183,839,738	17,108,504	16,718,048	458,987	453,497
13	ProvisionForRateRefundsAbstract (Less) (449.1) Provision for Rate Refunds
14	RevenuesNetOfProvisionForRefundsAbstract TOTAL Revenues Before Prov. for Refunds	1,339,785,176	1,183,839,738	17,108,504	16,718,048	458,987	453,497
15	OtherOperatingRevenuesAbstract Other Operating Revenues
16	ForfeitedDiscounts (450) Forfeited Discounts	5,785,312	7,021,236
17	MiscellaneousServiceRevenues (451) Miscellaneous Service Revenues	(b) 2,551,400	(e) 3,702,761
18	SalesOfWaterAndWaterPower (453) Sales of Water and Water Power
19	RentFromElectricProperty (454) Rent from Electric Property	11,201,890	10,670,459
20	InterdepartmentalRents (455) Interdepartmental Rents
21	OtherElectricRevenue (456) Other Electric Revenues	(c) 3,389,694	(f) 6,268,521
22	RevenuesFromTransmissionOfElectricityOfOthers (456.1) Revenues from Transmission of Electricity of Others	40,263,484	31,864,809
23	RegionalTransmissionServiceRevenues (457.1) Regional Control Service Revenues	10,148,719	4,487,023
24	MiscellaneousRevenue (457.2) Miscellaneous Revenues
25	OtherMiscellaneousOperatingRevenues Other Miscellaneous Operating Revenues
26	OtherOperatingRevenues TOTAL Other Operating Revenues	66,561,111	64,014,809
27	ElectricOperatingRevenues TOTAL Electric Operating Revenues	1,406,346,287	1,247,854,547
Line12, column (b) includes $ of unbilled revenues.
Line12, column (d) includes MWH relating to unbilled revenues

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: SmallOrCommercialSalesElectricOperatingRevenue

Basis of classification of Commercial and Industrial Sales Account 442: (a) Industrial - Standard Classification Manual; (b) Commercial - all other business or professional activities of a non-manufacturing nature.

(b) Concept: MiscellaneousServiceRevenues

Revenues from connections and reconnections.

(c) Concept: OtherElectricRevenue


MISO Mkt Sch 11 Wholesale Dist			$1,018,414
Ouachita Upgrades			970,860
Grid Modernization			2,866
MS Department of Revenue - Vendor discount			1,200
Third Party Sales of Inventory			(3,322)
Choctaw Interim Recovery Rider			(1,899,050)
Unbilled Revenue - Includes (102,252) MWH			(3,480,662)
Total			($3,389,694)

(d) Concept: SmallOrCommercialSalesElectricOperatingRevenue

Basis of classification of Commercial and Industrial Sales Account 442: (a) Industrial - Standard Classification Manual; (b) Commercial - all other business or professional activities of a non-manufacturing nature.

(e) Concept: MiscellaneousServiceRevenues

Revenues from connections and reconnections.

(f) Concept: OtherElectricRevenue


MISO Mkt Sch 11 Wholesale Dist			$1,092,062
Ouachita Upgrades			970,860
MS Department of Revenue - Vendor discount			1,200
Third Party Sales of Inventory			2,628
Choctaw Interim Recovery Rider			(7,886,741)
Unbilled Revenue - Includes 58,401 MWH			12,088,332
Other			$180
Total			$6,268,521

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

REGIONAL TRANSMISSION SERVICE REVENUES (Account 457.1)
The respondent shall report below the revenue collected for each service (i.e., control area administration, market administration, etc.) performed pursuant to a Commission approved tariff. All amounts separately billed must be detailed below.
Line No.	Description of Service (a)	Balance at End of Quarter 1 (b)	Balance at End of Quarter 2 (c)	Balance at End of Quarter 3 (d)	Balance at End of Year (e)
1	MISO Sch 1 Sched/Sys Ctrl/Disp	171,080	313,737	483,748	627,022
2	MISO Sch 2 Reactive	2,150,186	4,439,804	7,431,548	9,521,697
46	TOTAL	2,321,266	4,753,541	7,915,296	10,148,719

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	RS-38C Residential Service	3,604,198	380,038,908	260,890	13,815	0.1054
2	RS-38W Residential Water Heating Service	1,929,639	188,735,532	121,572	15,872	0.0978
3	PAL-17 Private Area Lighting	30,653	8,002,713	842	36,405	0.2611
4	UFL-16 Urban Flood Lighting	6	879	1	6,000	0.1465
5	RFL-16 Rural Flood Lighting	2	317	1	2,000	0.1585
6	DSL-16 Directional Security Lighting	1,657	444,139	65	25,492	0.2680
7	LED-2 LED Street and Area Lighting	1,900	1,052,188	96	19,792	0.5538
8	GS-298 General Lighting and Power		16,181
9	IPS-26 Irrigation Pumping Power			1
41	TOTAL Billed Residential Sales	5,568,055	(a) 578,258,495	383,468	14,520	0.1039
42	TOTAL Unbilled Rev. (See Instr. 6)
43	TOTAL	5,568,055	578,258,495	383,468	14,520	0.1039

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: ResidentialSalesBilled


Residential
Includes fuel adjustment revenues of:
RS-38C Residential Service			($71,392,510)
RS-38W Residential Water Heating Service			(38,134,405)
PAL-17 Private Area Lighting			(608,383)
UFL-16 Urban Flood Lighting			(126)
RFL-16 Rural Flood Lighting			(36)
DSL-16 Directional Security Lighting			(32,847)
GS-298 General Lighting and Power			—
HL-21 Public Highway & Park Lighting			—
LED-2 LED Street and Area Lighting			(37,742)
TOTAL RESIDENTIAL FUEL ADJUSTMENT REVENUES			($110,206,049)

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	GS-298 General Lighting and Power	2,380,582	277,240,712	63,894	37,258	0.1165
2	HLF-7 High Load Factor	1,116,925	80,447,803	310	3,602,984	0.0720
3	PAL-17 Private Area Lighting	15,799	4,402,504	874	18,077	0.2787
4	UFL-16 Urban Flood Lighting	254	36,783	21	12,095	0.1448
5	RFL-16 Rural Flood Lighting	7	1,303			0.1861
6	DSL-16 Directional Security Lighting	34,988	6,910,746	647	54,077	0.1975
7	LED-2 LED Street and Area Lighting	13,802	4,387,303	180	76,678	0.3179
8	B-34 Intermediate General Service	330,986	30,017,145	277	1,194,895	0.0907
9	SL-37 Municipal Street Lighting		26,597	4
10	TF-23 Traffic Control Signals	11	1,059	1	11,000	0.0963
11	FAYETTE	387	14,135	1	387,000	0.0365
12	IPS-26 Irrigation Pumping Power	2	794	2	1,000	0.3970
13	GS-298 MS Gen. Lghtg & Pwr Muni. Service	22	2,858	3	7,333	0.1299
14	QF-18		140	1
15	Miscellaneous		8,160	83
16	ALGS-10 Alternate Large General Service	406,577	24,164,310	6	67,762,833	0.0594
17	MP-22 Municipal Pumping Power Service	12	3,174			0.2645
18	GLP-17 Gen. Lghtg. & Pwr Redist. & Res.	1,366	141,853	1	1,366,000	0.1038
19	C-29 Large General Service	166,867	12,112,855	14	11,919,071	0.0726
20	SWH-20 Gen. Space and Water Heating Serv.	363	36,967	18	20,167	0.1018
21	RS-38C Residential Service	55	6,237	6	9,167	0.1134
22	RS-38W Residential Water Heating Service	16	1,427			0.0892
41	TOTAL Billed Small or Commercial	4,468,879	(a) 439,949,537	66,343	67,360	0.0984
42	TOTAL Unbilled Rev. Small or Commercial (See Instr. 6)
43	TOTAL Small or Commercial	4,468,879	(b) 439,949,537	66,343	67,360	0.0984

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: SmallOrCommercialSalesElectricOperatingRevenueBilled


Commercial
Includes Fuel Adjustment Revenues of:
GS-298 General Lighting and Power			($47,183,947)
B-34 Intermediate General Service			(6,557,849)
C-29 Large General Service			(3,308,914)
ALGS-10 Alternate Large General Service			(8,062,268)
HLF-7 High Load Factor General Service			(22,138,229)
FAYETTE			—
GLP-17 Gen. Lghtg. & Pwr for Redist. & Res.			(27,086)
DSL-16 Directional Security Lighting			(692,879)
SWH-20 Gen. Space and Water Heating Serv.			(7,192)
PAL-17 Private Area Lighting			($313,047)
UFL-16 Urban Flood Lighting			(5,051)
RFL-16 Rural Flood Lighting			(143)
RS-38C Residential Service			462
RS-38W Residential Water Heating Service			122
TF-23 Traffic Control Signal			(219)
MP-22 Municipal Pumping Power			(242)
IPS-26 Irrigation Pumping Power			(64)
HL-21 Public Highway & Park Lighting			—
SL-37 Municipal Street Lighting			—
LED-2 LED Street and Area Lighting			(273,765)
SE-29 State Institutions Service			—
GS-298 MS Gen L&P Muni Service			(437)
GS-298X Gen L&P TOU			—
TOTAL COMMERCIAL FUEL ADJUSTMENT REVENUES			($88,570,748)

(b) Concept: SmallOrCommercialSalesElectricOperatingRevenue

Basis of classification of Commercial and Industrial Sales Account 442: (a) Industrial - Standard Classification Manual; (b) Commercial - all other business or professional activities of a non-manufacturing nature.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	GS-298 General Lighting and Power	137,847	16,306,828	2,111	65,299	0.1183
2	HLF-7 High Load Factor	571,560	39,903,206	78	7,327,692	0.0698
3	PAL-17 Private Area Lighting	537	136,154	21	25,571	0.2535
4	UFL-16 Urban Flood Lighting	8	1,322	1	8,000	0.1653
5	RFL-16 Rural Flood Lighting	2	317			0.1585
6	DSL-16 Directional Security Lighting	2,288	424,079	20	114,400	0.1853
7	LED-2 LED Street and Area Lighting	478	132,743	3	159,333	0.2777
8	B-34 Intermediate General Service	160,962	15,966,544	90	1,788,467	0.0992
9	C-29 Large General Service	215,983	17,089,690	29	7,447,690	0.0791
10	IPS-26 Irrigation Pumping Power	20,202	3,764,213	1,567	12,892	0.1863
11	IP-33 Ice Manufacturing Plant Power	292	28,616	1	292,000	0.0980
12	ALGS-10 / Other	687,320	42,409,508	16	42,957,500	0.0617
13	Contract Rates	497,591	14,199,273	4	124,397,750	0.0285
14	GS-298X	2,599	335,490	63	41,254	0.1291
15	GS-298 MS Gen. Lghtg & Pwr Muni. Service	6	449	1	6,000	0.0748
16	RS-38C Residential Service			1
41	TOTAL Billed Large (or Ind.) Sales	2,297,663	(a) 150,697,534	4,006	573,555	0.0656
42	TOTAL Unbilled Rev. Large (or Ind.) (See Instr. 6)
43	TOTAL Large (or Ind.)	2,297,663	150,697,534	4,006	573,555	0.0656

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: LargeOrIndustrialSalesElectricOperatingRevenueBilled


Industrial
Includes Fuel Adjustment Revenues of:
GS-298 General Lighting and Power			($2,713,030)
B-34 Intermediate General Service			(3,175,945)
C-29 Large General Service			(4,280,627)
ALGS-10 / Other			(14,505,318)
HLF-7 High Load Factor General Service			(11,332,245)
DSL-16 Directional Security Lighting			(45,310)
IPS-26 Irrigation Pumping Power			(409,918)
IP-33 Ice Manufacturing Plant Power			(5,734)
PAL-17 Private Area Lighting Service			(10,639)
UFL-16 Urban Flood Lighting Service			($155)
RFL-16 Rural Flood Lighting Service			(36)
SL-37 Municipal Street Lighting			—
LED-2 LED Street and Area Lighting			(9,478)
GS-298 MS Gen L&P Muni Service			155
GS-298X Gen L&P TOU			(51,578)
RS-38W Residential Water Heating Service			—
TOTAL INDUSTRIAL FUEL ADJUSTMENT REVENUES			($36,539,858)

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41	TOTAL Billed Commercial and Industrial Sales
42	TOTAL Unbilled Rev. (See Instr. 6)
43	TOTAL

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	SL-37 Municipal Street Lighting	60,668	14,250,289	137	442,832	0.2349
2	HL-21 Public Highway & Park Lighting	12,521	1,018,499	89	140,685	0.0813
3	TF-23 Traffic Control Signals	4,021	466,746	194	20,727	0.1161
4	LED-2 LED Street and Area Lighting	76	35,362	9	8,444	0.4653
41	TOTAL Billed Public Street and Highway Lighting	77,286	(a) 15,770,896	429	180,154	0.2041
42	TOTAL Unbilled Rev. (See Instr. 6)
43	TOTAL	77,286	15,770,896	429	180,154	0.2041

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: PublicStreetAndHighwayLightingBilled


Public Street and Highway Lighting
Includes Fuel Adjustment Revenues of:
TF-23 Traffic Control Signals			($79,601)
HL-21 Public Highway & Park Lighting			(248,064)
SL-37 Municipal Street Lighting			(1,200,677)
DSL-16 Directional Security Lighting			—
PAL-17 Private Area Lighting Service			—
LED-2 LED Street and Area Lighting			(1,508)
TOTAL PUBLIC STREET AND HIGHWAY LIGHTING FUEL ADJUSTMENT REVENUES			($1,529,850)

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	GS-298 MS Gen. Lghtg & Pwr Muni. Service	176,500	16,374,576	2,690	65,613	0.0928
2	MP-22 Municipal Pumping Power Service	84,206	8,489,829	1,948	43,227	0.1008
3	SE-29 State Institutions	69,011	4,913,299	8	8,626,375	0.0712
4	GS-298 General Lighting and Power	180	21,650	8	22,500	0.1203
5	SL-37 Municipal Street Lighting		537
6	PAL-17 Private Area Lighting	489	125,637	19	25,737	0.2569
7	DSL-16 Directional Security Lighting	2,333	447,621	61	38,246	0.1919
8	LED-2 LED Street and Area Lighting	328	103,008	7	46,857	0.3140
9	UFL-16 Urban Flood Lighting	5	585			0.1170
41	TOTAL Billed Other Sales to Public Authorities	333,052	(a) 30,476,742	4,741	70,249	0.0915
42	TOTAL Unbilled Rev. (See Instr. 6)
43	TOTAL	333,052	30,476,742	4,741	70,249	0.0915

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: OtherSalesToPublicAuthoritiesBilled


Other Sales to Public Authorities
Includes Fuel Adjustment Revenues of:
GS-298 MS Gen. Lghtg & Pwr Muni.Service			($3,496,573)
MP-22 Municipal Pumping Power Service			(1,664,231)
SE-29 State Institutions			(1,369,170)
DSL-16 Directional Security Lighting			(46,179)
PAL-17 Private Area Lighting			(9,676)
UFL-16 Urban Flood Lighting			(90)
HL-21 Public Highway & Park Ltg			—
GS-298 General Lighting and Power			(3,491)
RS-38W Residential Water Heating Service			—
LED-2 LED Street and Area Lighting			(6,488)
B-34 Intermediate General Service			—
TOTAL OTHER SALES TO PUBLIC AUTH FUEL ADJ REV			($6,595,898)

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
41	TOTAL Billed - All Accounts	12,744,935	1,215,153,204	458,987	27,768	0.0953
42	TOTAL Unbilled Rev. (See Instr. 6) - All Accounts
43	TOTAL - All Accounts	12,744,935	1,215,153,204	458,987	27,768	0.0953

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

SALES FOR RESALE (Account 447)
Report all sales for resale (i.e., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity ( i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326). Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years. SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less. LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years. OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote. AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter "Subtotal - RQ" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RQ" in column (a) after this Listing. Enter "Total'' in column (a) as the Last Line of the schedule. Report subtotals and total for columns (g) through (k). In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided. For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. Report in column (g) the megawatt hours shown on bills rendered to the purchaser. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column (j). Explain in a footnote all components of the amount shown in column (j). Report in column (k) the total charge shown on bills rendered to the purchaser. The data in column (g) through (k) must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RQ" amount in column (g) must be reported as Requirements Sales For Resale on Page 401, line 23. The "Subtotal - Non-RQ" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401,line 24. Footnote entries as required and provide explanations following all required data.
					ACTUAL DEMAND (MW)			REVENUE
Line No.	Name of Company or Public Authority (Footnote Affiliations) (a)	Statistical Classification (b)	FERC Rate Schedule or Tariff Number (c)	Average Monthly Billing Demand (MW) (d)	Average Monthly NCP Demand (e)	Average Monthly CP Demand (f)	Megawatt Hours Sold (g)	Demand Charges ($) (h)	Energy Charges ($) (i)	Other Charges ($) (j)	Total ($) (h+i+j) (k)
1	Midcontinent ISO, Inc.	OS					4,363,569	31,532	122,203,045	(a) 1,972,607	124,207,184
2	Entergy System Power Pool	OS	94							(b) 424,788	424,788
15	Subtotal - RQ
16	Subtotal-Non-RQ						4,363,569	31,532	122,203,045	2,397,395	124,631,972
17	Total						4,363,569	31,532	122,203,045	2,397,395	124,631,972

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: OtherChargesRevenueSalesForResale


MISO Residual Load			$743,800
MISO Uplift			1,228,807
Total			$1,972,607

(b) Concept: OtherChargesRevenueSalesForResale

Settlement of Rough Production Cost Equalization per FERC Docket Nos. EL10-65-008 and EL10-65-009.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

ELECTRIC OPERATION AND MAINTENANCE EXPENSES
If the amount for previous year is not derived from previously reported figures, explain in footnote.
Line No.	Account (a)	Amount for Current Year (b)	Amount for Previous Year (c) (c)
1	PowerProductionExpensesAbstract 1. POWER PRODUCTION EXPENSES
2	SteamPowerGenerationAbstract A. Steam Power Generation
3	SteamPowerGenerationOperationAbstract Operation
4	OperationSupervisionAndEngineeringSteamPowerGeneration (500) Operation Supervision and Engineering	4,544,995	4,931,179
5	FuelSteamPowerGeneration (501) Fuel	(a) 318,054,549	(b) 242,747,661
6	SteamExpensesSteamPowerGeneration (502) Steam Expenses	2,278,994	2,286,355
7	SteamFromOtherSources (503) Steam from Other Sources
8	SteamTransferredCredit (Less) (504) Steam Transferred-Cr.
9	ElectricExpensesSteamPowerGeneration (505) Electric Expenses	603,100	643,878
10	MiscellaneousSteamPowerExpenses (506) Miscellaneous Steam Power Expenses	8,181,881	7,842,840
11	RentsSteamPowerGeneration (507) Rents	21,732	448,453
12	Allowances (509) Allowances	26,384	50,040
13	SteamPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 4 thru 12)	333,711,635	258,950,406
14	SteamPowerGenerationMaintenanceAbstract Maintenance
15	MaintenanceSupervisionAndEngineeringSteamPowerGeneration (510) Maintenance Supervision and Engineering	500,249	557,530
16	MaintenanceOfStructuresSteamPowerGeneration (511) Maintenance of Structures	745,604	981,398
17	MaintenanceOfBoilerPlantSteamPowerGeneration (512) Maintenance of Boiler Plant	7,965,946	7,932,147
18	MaintenanceOfElectricPlantSteamPowerGeneration (513) Maintenance of Electric Plant	3,517,853	2,987,396
19	MaintenanceOfMiscellaneousSteamPlant (514) Maintenance of Miscellaneous Steam Plant	19,129,509	17,193,594
20	SteamPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of Lines 15 thru 19)	31,859,161	29,652,065
21	PowerProductionExpensesSteamPower TOTAL Power Production Expenses-Steam Power (Enter Total of Lines 13 & 20)	365,570,796	288,602,471
22	NuclearPowerGenerationAbstract B. Nuclear Power Generation
23	NuclearPowerGenerationOperationAbstract Operation
24	OperationSupervisionAndEngineeringNuclearPowerGeneration (517) Operation Supervision and Engineering
25	NuclearFuelExpense (518) Fuel
26	CoolantsAndWater (519) Coolants and Water
27	SteamExpensesNuclearPowerGeneration (520) Steam Expenses
28	SteamFromOtherSourcesNuclearPowerGeneration (521) Steam from Other Sources
29	SteamTransferredCreditNuclearPowerGeneration (Less) (522) Steam Transferred-Cr.
30	ElectricExpensesNuclearPowerGeneration (523) Electric Expenses
31	MiscellaneousNuclearPowerExpenses (524) Miscellaneous Nuclear Power Expenses
32	RentsNuclearPowerGeneration (525) Rents
33	NuclearPowerGenerationOperationsExpense TOTAL Operation (Enter Total of lines 24 thru 32)
34	NuclearPowerGenerationMaintenanceAbstract Maintenance
35	MaintenanceSupervisionAndEngineeringNuclearPowerGeneration (528) Maintenance Supervision and Engineering
36	MaintenanceOfStructuresNuclearPowerGeneration (529) Maintenance of Structures
37	MaintenanceOfReactorPlantEquipmentNuclearPowerGeneration (530) Maintenance of Reactor Plant Equipment
38	MaintenanceOfElectricPlantNuclearPowerGeneration (531) Maintenance of Electric Plant
39	MaintenanceOfMiscellaneousNuclearPlant (532) Maintenance of Miscellaneous Nuclear Plant
40	NuclearPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of lines 35 thru 39)
41	PowerProductionExpensesNuclearPower TOTAL Power Production Expenses-Nuclear. Power (Enter Total of lines 33 & 40)
42	HydraulicPowerGenerationAbstract C. Hydraulic Power Generation
43	HydraulicPowerGenerationOperationAbstract Operation
44	OperationSupervisionAndEngineeringHydraulicPowerGeneration (535) Operation Supervision and Engineering
45	WaterForPower (536) Water for Power
46	HydraulicExpenses (537) Hydraulic Expenses
47	ElectricExpensesHydraulicPowerGeneration (538) Electric Expenses
48	MiscellaneousHydraulicPowerGenerationExpenses (539) Miscellaneous Hydraulic Power Generation Expenses
49	RentsHydraulicPowerGeneration (540) Rents
50	HydraulicPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 44 thru 49)
51	HydraulicPowerGenerationContinuedAbstract C. Hydraulic Power Generation (Continued)
52	HydraulicPowerGenerationMaintenanceAbstract Maintenance
53	MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration (541) Mainentance Supervision and Engineering
54	MaintenanceOfStructuresHydraulicPowerGeneration (542) Maintenance of Structures
55	MaintenanceOfReservoirsDamsAndWaterways (543) Maintenance of Reservoirs, Dams, and Waterways
56	MaintenanceOfElectricPlantHydraulicPowerGeneration (544) Maintenance of Electric Plant
57	MaintenanceOfMiscellaneousHydraulicPlant (545) Maintenance of Miscellaneous Hydraulic Plant
58	HydraulicPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of lines 53 thru 57)
59	PowerProductionExpensesHydraulicPower TOTAL Power Production Expenses-Hydraulic Power (Total of Lines 50 & 58)
60	OtherPowerGenerationAbstract D. Other Power Generation
61	OtherPowerGenerationOperationAbstract Operation
62	OperationSupervisionAndEngineeringOtherPowerGeneration (546) Operation Supervision and Engineering	994,428	957,089
63	Fuel (547) Fuel
64	GenerationExpenses (548) Generation Expenses	809,873	794,577
64.1	OperationOfEnergyStorageEquipment (548.1) Operation of Energy Storage Equipment
65	MiscellaneousOtherPowerGenerationExpenses (549) Miscellaneous Other Power Generation Expenses	8,944,873	8,973,730
66	RentsOtherPowerGeneration (550) Rents	92,131	87,883
67	OtherPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 62 thru 67)	10,841,305	10,813,279
68	OtherPowerGenerationMaintenanceAbstract Maintenance
69	MaintenanceSupervisionAndEngineeringOtherPowerGeneration (551) Maintenance Supervision and Engineering	37,459	15,959
70	MaintenanceOfStructures (552) Maintenance of Structures	341,996	336,456
71	MaintenanceOfGeneratingAndElectricPlant (553) Maintenance of Generating and Electric Plant	5,790,155	8,003,441
71.1	MaintenanceOfEnergyStorageEquipmentOtherPowerGeneration (553.1) Maintenance of Energy Storage Equipment
72	MaintenanceOfMiscellaneousOtherPowerGenerationPlant (554) Maintenance of Miscellaneous Other Power Generation Plant	526,849	351,149
73	OtherPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of Lines 69 thru 72)	6,696,459	8,707,005
74	PowerProductionExpensesOtherPower TOTAL Power Production Expenses-Other Power (Enter Total of Lines 67 & 73)	17,537,764	19,520,284
75	OtherPowerSuplyExpensesAbstract E. Other Power Supply Expenses
76	PurchasedPower (555) Purchased Power	297,967,897	240,457,288
76.1	PowerPurchasedForStorageOperations (555.1) Power Purchased for Storage Operations	0
77	SystemControlAndLoadDispatchingElectric (556) System Control and Load Dispatching	676,994	734,298
78	OtherExpensesOtherPowerSupplyExpenses (557) Other Expenses	136,362,952	55,543,803
79	OtherPowerSupplyExpense TOTAL Other Power Supply Exp (Enter Total of Lines 76 thru 78)	162,281,939	185,647,783
80	PowerProductionExpenses TOTAL Power Production Expenses (Total of Lines 21, 41, 59, 74 & 79)	545,390,499	493,770,538
81	TransmissionExpensesAbstract 2. TRANSMISSION EXPENSES
82	TransmissionExpensesOperationAbstract Operation
83	OperationSupervisionAndEngineeringElectricTransmissionExpenses (560) Operation Supervision and Engineering	2,694,179	2,462,080
85	LoadDispatchReliability (561.1) Load Dispatch-Reliability
86	LoadDispatchMonitorAndOperateTransmissionSystem (561.2) Load Dispatch-Monitor and Operate Transmission System	2,152,248	2,033,776
87	LoadDispatchTransmissionServiceAndScheduling (561.3) Load Dispatch-Transmission Service and Scheduling	45,110	63,278
88	SchedulingSystemControlAndDispatchServices (561.4) Scheduling, System Control and Dispatch Services	4,182,192	3,821,714
89	ReliabilityPlanningAndStandardsDevelopment (561.5) Reliability, Planning and Standards Development	333,098	413,688
90	TransmissionServiceStudies (561.6) Transmission Service Studies	2,910
91	GenerationInterconnectionStudies (561.7) Generation Interconnection Studies
92	ReliabilityPlanningAndStandardsDevelopmentServices (561.8) Reliability, Planning and Standards Development Services	552,456	495,548
93	StationExpensesTransmissionExpense (562) Station Expenses	209,844	275,567
93.1	OperationOfEnergyStorageEquipmentTransmissionExpense (562.1) Operation of Energy Storage Equipment
94	OverheadLineExpense (563) Overhead Lines Expenses	812,538	879,265
95	UndergroundLineExpensesTransmissionExpense (564) Underground Lines Expenses
96	TransmissionOfElectricityByOthers (565) Transmission of Electricity by Others	7,731,993	3,359,878
97	MiscellaneousTransmissionExpenses (566) Miscellaneous Transmission Expenses	907,443	1,118,660
98	RentsTransmissionElectricExpense (567) Rents	686,521	593,623
99	TransmissionOperationExpense TOTAL Operation (Enter Total of Lines 83 thru 98)	20,310,532	15,517,077
100	TransmissionMaintenanceAbstract Maintenance
101	MaintenanceSupervisionAndEngineeringElectricTransmissionExpenses (568) Maintenance Supervision and Engineering	2,473,668	2,898,678
102	MaintenanceOfStructuresTransmissionExpense (569) Maintenance of Structures	235,382	163,955
103	MaintenanceOfComputerHardwareTransmission (569.1) Maintenance of Computer Hardware	2,433
104	MaintenanceOfComputerSoftwareTransmission (569.2) Maintenance of Computer Software	54,133	19,230
105	MaintenanceOfCommunicationEquipmentElectricTransmission (569.3) Maintenance of Communication Equipment
106	MaintenanceOfMiscellaneousRegionalTransmissionPlant (569.4) Maintenance of Miscellaneous Regional Transmission Plant
107	MaintenanceOfStationEquipmentTransmission (570) Maintenance of Station Equipment	1,921,776	1,691,155
107.1	MaintenanceOfEnergyStorageEquipmentTransmission (570.1) Maintenance of Energy Storage Equipment
108	MaintenanceOfOverheadLinesTransmission (571) Maintenance of Overhead Lines	3,647,894	4,084,725
109	MaintenanceOfUndergroundLinesTransmission (572) Maintenance of Underground Lines
110	MaintenanceOfMiscellaneousTransmissionPlant (573) Maintenance of Miscellaneous Transmission Plant	64,442	34,490
111	TransmissionMaintenanceExpenseElectric TOTAL Maintenance (Total of Lines 101 thru 110)	8,399,728	8,892,233
112	TransmissionExpenses TOTAL Transmission Expenses (Total of Lines 99 and 111)	28,710,260	24,409,310
113	RegionalMarketExpensesAbstract 3. REGIONAL MARKET EXPENSES
114	RegionalMarketExpensesOperationAbstract Operation
115	OperationSupervision (575.1) Operation Supervision
116	DayAheadAndRealTimeMarketAdministration (575.2) Day-Ahead and Real-Time Market Facilitation
117	TransmissionRightsMarketAdministration (575.3) Transmission Rights Market Facilitation
118	CapacityMarketAdministration (575.4) Capacity Market Facilitation
119	AncillaryServicesMarketAdministration (575.5) Ancillary Services Market Facilitation
120	MarketMonitoringAndCompliance (575.6) Market Monitoring and Compliance
121	MarketFacilitationMonitoringAndComplianceServices (575.7) Market Facilitation, Monitoring and Compliance Services	2,673,202	2,868,273
122	RentsRegionalMarketExpenses (575.8) Rents
123	RegionalMarketOperationExpense Total Operation (Lines 115 thru 122)	2,673,202	2,868,273
124	RegionalMarketExpensesMaintenanceAbstract Maintenance
125	MaintenanceOfStructuresAndImprovementsRegionalMarketExpenses (576.1) Maintenance of Structures and Improvements
126	MaintenanceOfComputerHardware (576.2) Maintenance of Computer Hardware
127	MaintenanceOfComputerSoftware (576.3) Maintenance of Computer Software
128	MaintenanceOfCommunicationEquipmentRegionalMarketExpenses (576.4) Maintenance of Communication Equipment
129	MaintenanceOfMiscellaneousMarketOperationPlant (576.5) Maintenance of Miscellaneous Market Operation Plant
130	RegionalMarketMaintenanceExpense Total Maintenance (Lines 125 thru 129)
131	RegionalMarketExpenses TOTAL Regional Transmission and Market Operation Expenses (Enter Total of Lines 123 and 130)	2,673,202	2,868,273
132	DistributionExpensesAbstract 4. DISTRIBUTION EXPENSES
133	DistributionExpensesOperationAbstract Operation
134	OperationSupervisionAndEngineeringDistributionExpense (580) Operation Supervision and Engineering	11,477,640	9,584,852
135	LoadDispatching (581) Load Dispatching	148,665	139,380
136	StationExpensesDistribution (582) Station Expenses	185,661	215,025
137	OverheadLineExpenses (583) Overhead Line Expenses	1,037,680	1,250,430
138	UndergroundLineExpenses (584) Underground Line Expenses	1,720,063	1,218,302
138.1	OperationOfEnergyStorageEquipmentDistribution (584.1) Operation of Energy Storage Equipment
139	StreetLightingAndSignalSystemExpenses (585) Street Lighting and Signal System Expenses	155,799	123,147
140	MeterExpenses (586) Meter Expenses	2,075,232	2,791,566
141	CustomerInstallationsExpenses (587) Customer Installations Expenses	779,122	656,839
142	MiscellaneousDistributionExpenses (588) Miscellaneous Expenses	3,716,345	2,812,165
143	RentsDistributionExpense (589) Rents	2,454,909	2,874,025
144	DistributionOperationExpensesElectric TOTAL Operation (Enter Total of Lines 134 thru 143)	23,751,116	21,665,731
145	DistributionExpensesMaintenanceAbstract Maintenance
146	MaintenanceSupervisionAndEngineering (590) Maintenance Supervision and Engineering	974,260	913,865
147	MaintenanceOfStructuresDistributionExpense (591) Maintenance of Structures	714,007	678,958
148	MaintenanceOfStationEquipment (592) Maintenance of Station Equipment	1,052,921	1,023,179
148.1	MaintenanceOfEnergyStorageEquipment (592.2) Maintenance of Energy Storage Equipment
149	MaintenanceOfOverheadLines (593) Maintenance of Overhead Lines	29,873,238	27,056,662
150	MaintenanceOfUndergroundLines (594) Maintenance of Underground Lines	1,143,003	980,781
151	MaintenanceOfLineTransformers (595) Maintenance of Line Transformers	391,239	269,193
152	MaintenanceOfStreetLightingAndSignalSystems (596) Maintenance of Street Lighting and Signal Systems	741,910	454,915
153	MaintenanceOfMeters (597) Maintenance of Meters	42,883	86,080
154	MaintenanceOfMiscellaneousDistributionPlant (598) Maintenance of Miscellaneous Distribution Plant	1,480,506	1,475,525
155	DistributionMaintenanceExpenseElectric TOTAL Maintenance (Total of Lines 146 thru 154)	36,413,967	32,939,158
156	DistributionExpenses TOTAL Distribution Expenses (Total of Lines 144 and 155)	60,165,083	54,604,889
157	CustomerAccountsExpensesAbstract 5. CUSTOMER ACCOUNTS EXPENSES
158	CustomerAccountsExpensesOperationsAbstract Operation
159	SupervisionCustomerAccountExpenses (901) Supervision	208,362	402,411
160	MeterReadingExpenses (902) Meter Reading Expenses	3,178,288	5,065,550
161	CustomerRecordsAndCollectionExpenses (903) Customer Records and Collection Expenses	19,322,183	14,467,811
162	UncollectibleAccounts (904) Uncollectible Accounts	3,683,745	3,217,577
163	MiscellaneousCustomerAccountsExpenses (905) Miscellaneous Customer Accounts Expenses	103,213	46,582
164	CustomerAccountExpenses TOTAL Customer Accounts Expenses (Enter Total of Lines 159 thru 163)	26,495,791	23,199,931
165	CustomerServiceAndInformationalExpensesAbstract 6. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES
166	CustomerServiceAndInformationalExpensesOperationAbstract Operation
167	SupervisionCustomerServiceAndInformationExpenses (907) Supervision	354,409	593,566
168	CustomerAssistanceExpenses (908) Customer Assistance Expenses	3,822,364	11,375,343
169	InformationalAndInstructionalAdvertisingExpenses (909) Informational and Instructional Expenses	811,223	531,566
170	MiscellaneousCustomerServiceAndInformationalExpenses (910) Miscellaneous Customer Service and Informational Expenses	1,512,884	1,267,319
171	CustomerServiceAndInformationExpenses TOTAL Customer Service and Information Expenses (Total Lines 167 thru 170)	6,500,880	13,767,794
172	SalesExpenseAbstract 7. SALES EXPENSES
173	SalesExpenseOperationAbstract Operation
174	SupervisionSalesExpense (911) Supervision	505	271
175	DemonstratingAndSellingExpenses (912) Demonstrating and Selling Expenses	229,639	21,626
176	AdvertisingExpenses (913) Advertising Expenses	898,185	1,118,442
177	MiscellaneousSalesExpenses (916) Miscellaneous Sales Expenses	56,519	112,912
178	SalesExpenses TOTAL Sales Expenses (Enter Total of Lines 174 thru 177)	1,184,848	1,253,251
179	AdministrativeAndGeneralExpensesAbstract 8. ADMINISTRATIVE AND GENERAL EXPENSES
180	AdministrativeAndGeneralExpensesOperationAbstract Operation
181	AdministrativeAndGeneralSalaries (920) Administrative and General Salaries	31,101,577	27,935,760
182	OfficeSuppliesAndExpenses (921) Office Supplies and Expenses	1,363,669	1,237,435
183	AdministrativeExpensesTransferredCredit (Less) (922) Administrative Expenses Transferred-Credit
184	OutsideServicesEmployed (923) Outside Services Employed	17,097,225	13,927,359
185	PropertyInsurance (924) Property Insurance	23,014,869	21,996,120
186	InjuriesAndDamages (925) Injuries and Damages	2,148,906	5,952,199
187	EmployeePensionsAndBenefits (926) Employee Pensions and Benefits	26,586,368	25,191,058
188	FranchiseRequirements (927) Franchise Requirements
189	RegulatoryCommissionExpenses (928) Regulatory Commission Expenses	3,071,197	4,049,545
190	DuplicateChargesCredit (929) (Less) Duplicate Charges-Cr.
191	GeneralAdvertisingExpenses (930.1) General Advertising Expenses	1,019,129	624,724
192	MiscellaneousGeneralExpenses (930.2) Miscellaneous General Expenses	3,932,845	4,335,683
193	RentsAdministrativeAndGeneralExpense (931) Rents	501,708	782,449
194	AdministrativeAndGeneralOperationExpense TOTAL Operation (Enter Total of Lines 181 thru 193)	109,837,493	106,032,332
195	AdministrativeAndGeneralExpensesMaintenanceAbstract Maintenance
196	MaintenanceOfGeneralPlant (935) Maintenance of General Plant	1,322,449	1,250,864
197	AdministrativeAndGeneralExpenses TOTAL Administrative & General Expenses (Total of Lines 194 and 196)	111,159,942	107,283,196
198	OperationsAndMaintenanceExpensesElectric TOTAL Electric Operation and Maintenance Expenses (Total of Lines 80, 112, 131, 156, 164, 171, 178, and 197)	782,280,505	721,157,182

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: FuelSteamPowerGeneration

Includes ($21,499,986) relating to certain gas hedging activities.

(b) Concept: FuelSteamPowerGeneration

Includes $8,359,880 relating to certain gas hedging activities.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

PURCHASED POWER (Account 555)
Report all power purchases made during the year. Also report exchanges of electricity (i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service. Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. Report in column (g) the megawatthours shown on bills rendered to the respondent, excluding purchases for energy storage. Report in column (h) the megawatthours shown on bills rendered to the respondent for energy storage purchases. Report in columns (i) and (j) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. Report demand charges in column (k), energy charges in column (l), and the total of any other types of charges, including out-of-period adjustments, in column (m). Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (n) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (m) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. The data in columns (g) through (n) must be totaled on the last line of the schedule. The total amount in columns (g) and (h) must be reported as Purchases on Page 401, line 10. The total amount in column (i) must be reported as Exchange Received on Page 401, line 12. The total amount in column (j) must be reported as Exchange Delivered on Page 401, line 13. Footnote entries as required and provide explanations following all required data.
					Actual Demand (MW)				POWER EXCHANGES		COST/SETTLEMENT OF POWER
Line No.	NameOfCompanyOrPublicAuthorityProvidingPurchasedPower Name of Company or Public Authority (Footnote Affiliations) (a)	StatisticalClassificationCode Statistical Classification (b)	RateScheduleTariffNumber Ferc Rate Schedule or Tariff Number (c)	AverageMonthlyBillingDemand Average Monthly Billing Demand (MW) (d)	AverageMonthlyNonCoincidentPeakDemand Average Monthly NCP Demand (e)	AverageMonthlyCoincidentPeakDemand Average Monthly CP Demand (f)	MegawattHoursPurchasedOtherThanStorage MegaWatt Hours Purchased (Excluding for Energy Storage) (g)	MegawattHoursPurchasedForEnergyStorage MegaWatt Hours Purchased for Energy Storage (h)	EnergyReceivedThroughPowerExchanges MegaWatt Hours Received (i)	EnergyDeliveredThroughPowerExchanges MegaWatt Hours Delivered (j)	DemandChargesOfPurchasedPower Demand Charges ($) (k)	EnergyChargesOfPurchasedPower Energy Charges ($) (l)	OtherChargesOfPurchasedPower Other Charges ($) (m)	SettlementOfPower Total (k+l+m) of Settlement ($) (n)
1	Energy System Power Pool	OS
2	(a) System Energy Resources, Inc.	OS					3,495,832				165,760,833	19,243,421	(c) 3,760,835	188,765,089
3	(b) Entergy Arkansas, LLC	LU					735,998				34,890,845	4,051,465		38,942,310
4	Terra Miss Nitrogen	OS					29					1,123		1,123
5	CF Industries Nitrogen, LLC	OS					6,485					174,799		174,799
6	Midcontinent ISO, Inc.	OS					1,686,007				733	74,121,232	(d) 4,043,148	70,077,351
7	Small Residential Generation	OS					996					29,283		29,283
8	EDF Trading North America, LLC	OS											(e) 22,058	22,058
15	TOTAL						5,925,347	0	0	0	200,650,945	97,621,323	304,371	297,967,897

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower

Energy and capacity charges from the Grand Gulf Nuclear Power Plant.

(b) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower

Energy and capacity charges associated with MSS-4.

(c) Concept: OtherChargesOfPurchasedPower

Represents $14,072,098 for deferral on over/under recovery under the Grand Gulf Rider and ($10,311,263) for the turnaround of the Grand Gulf Accelerated Recovery Tariff approved by the FERC that provided for the acceleration of Entergy Arkansas's and Entergy Mississippi's Grand Gulf purchased power obligations with System Energy Resources.

(d) Concept: OtherChargesOfPurchasedPower


			CHARGES
MISO Ancillary			$1,873,470
MISO Congestion			(10,631,799)
MISO Losses			(2,253,925)
MISO Residual Load			441,009
MISO Uplift			6,340,943
MISO Administration			187,154
Total Other Purchases from MISO			($4,043,148)

(e) Concept: OtherChargesOfPurchasedPower

Related to the sale of Entergy Mississippi's Auction Revenue Rights allocated to Entergy Mississippi as part of its participation in MISO.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")

Report all transmission of electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers for the quarter.
Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c).
Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c).
In column (d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO - Firm Network Service for Others, FNS - Firm Network Transmission Service for Self, LFP - "Long-Term Firm Point to Point Transmission Service, OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point to Point Transmission Reservation, NF - non-firm transmission service, OS - Other Transmission Service and AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes.
In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided.
Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column (f), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract.
Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain.
Report in column (i) and (j) the total megawatthours received and delivered.
In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (I), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (0) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered.
The total amounts in columns (i) and (j) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 16 and 17, respectively.
Footnote entries and provide explanations following all required data.

TRANSFER OF ENERGY

REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS

Line No.

(a)

(b)

(c)

(d)

(e)

(f)

(g)

(h)

(i)

(j)

(k)

(l)

(m)

(n)

1

MISO

Various

40,263,484

35

TOTAL

0

40,263,484

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

TRANSMISSION OF ELECTRICITY BY ISO/RTOs
Report in Column (a) the Transmission Owner receiving revenue for the transmission of electricity by the ISO/RTO. Use a separate line of data for each distinct type of transmission service involving the entities listed in Column (a). In Column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO – Firm Network Service for Others, FNS – Firm Network Transmission Service for Self, LFP – Long-Term Firm Point-to-Point Transmission Service, OLF – Other Long-Term Firm Transmission Service, SFP – Short-Term Firm Point-to-Point Transmission Reservation, NF – Non-Firm Transmission Service, OS – Other Transmission Service and AD- Out-of-Period Adjustments. Use this code for any accounting adjustments or “true-ups” for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes. In column (c) identify the FERC Rate Schedule or tariff Number, on separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (b) was provided. In column (d) report the revenue amounts as shown on bills or vouchers. Report in column (e) the total revenues distributed to the entity listed in column (a).
Line No.	Payment Received by (Transmission Owner Name) (a)	Statistical Classification (b)	FERC Rate Schedule or Tariff Number (c)	Total Revenue by Rate Schedule or Tariff (d)	Total Revenue (e)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
40	TOTAL

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565)
Report all transmission, i.e. wheeling or electricity provided by other electric utilities, cooperatives, municipalities, other public authorities, qualifying facilities, and others for the quarter. In column (a) report each company or public authority that provided transmission service. Provide the full name of the company, abbreviate if necessary, but do not truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation with the transmission service provider. Use additional columns as necessary to report all companies or public authorities that provided transmission service for the quarter reported. In column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNS - Firm Network Transmission Service for Self, LFP - Long-Term Firm Point-to-Point Transmission Reservations. OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point-to- Point Transmission Reservations, NF - Non-Firm Transmission Service, and OS - Other Transmission Service. See General Instructions for definitions of statistical classifications. Report in column (c) and (d) the total megawatt hours received and delivered by the provider of the transmission service. Report in column (e), (f) and (g) expenses as shown on bills or vouchers rendered to the respondent. In column (e) report the demand charges and in column (f) energy charges related to the amount of energy transferred. On column (g) report the total of all other charges on bills or vouchers rendered to the respondent, including any out of period adjustments. Explain in a footnote all components of the amount shown in column (g). Report in column (h) the total charge shown on bills rendered to the respondent. If no monetary settlement was made, enter zero in column (h). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. Enter ""TOTAL"" in column (a) as the last line. Footnote entries and provide explanations following all required data.
			TRANSFER OF ENERGY		EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERS
Line No.	NameOfCompanyOrPublicAuthorityTransmissionOfElectricityByOthers Name of Company or Public Authority (Footnote Affiliations) (a)	StatisticalClassificationCode Statistical Classification (b)	TransmissionOfElectricityByOthersEnergyReceived MegaWatt Hours Received (c)	TransmissionOfElectricityByOthersEnergyDelivered MegaWatt Hours Delivered (d)	DemandChargesTransmissionOfElectricityByOthers Demand Charges ($) (e)	EnergyChargesTransmissionOfElectricityByOthers Energy Charges ($) (f)	OtherChargesTransmissionOfElectricityByOthers Other Charges ($) (g)	ChargesForTransmissionOfElectricityByOthers Total Cost of Transmission ($) (h)
1	Midcontinent Independent System Operator Inc				(a) 7,720,535		(b) 11,458	7,731,993
	TOTAL		0	0	7,720,535	0	11,458	7,731,993

FOOTNOTE DATA

(a) Concept: DemandChargesTransmissionOfElectricityByOthers

The Utility operating companies are transmission owning members of the Midcontinent Independent System Operator (MISO) RTO. MISO is the transmission provider under the MISO Attachment O. Entergy Mississippi incurred charges from MISO for the purchase of network transmission service under the MISO Attachment O. MISO calculated the network service charges applicable to Entergy Mississippi and billed the entity for such service.

(b) Concept: OtherChargesTransmissionOfElectricityByOthers

Network upgrade charges incurred from MISO under the MISO Attachment O. Rates are calculated under Attachment GG. Charges are related to the MTEP (MISO Transmission Expansion Plan).

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

MISCELLANEOUS GENERAL EXPENSES (Account 930.2) (ELECTRIC)
Line No.	Description (a)	Amount (b)
1	IndustryAssociationDues Industry Association Dues	496,189
2	NuclearPowerResearchExpenses Nuclear Power Research Expenses
3	OtherExperimentalAndGeneralResearchExpenses Other Experimental and General Research Expenses
4	PublicationAndDistributionExpensesForSecuritiesToStockholders Pub and Dist Info to Stkhldrs...expn servicing outstanding Securities	307,835
5	OtherMiscellaneousGeneralExpenses Oth Expn greater than or equal to 5,000 show purpose, recipient, amount. Group if less than $5,000
6	5% surcharge on regulated billings to non-regulated affiliates	401,740
7	Directors meetings and expenses	60,035
8	Section 263A research - tax services	15,701
9	System aircraft	335,873
10	Corporate purchasing card rebates	62,783
11	IT hardware applications/service contracts	3,170,041
12	Mobile device services	7,414
13	HR leadership development	13,885
14	Travel to reimburse project	9,520
15	Other	85
46	MiscellaneousGeneralExpenses TOTAL	3,932,845

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

Depreciation and Amortization of Electric Plant (Account 403, 404, 405)
Report in section A for the year the amounts for: (b) Depreciation Expense (Account 403); (c) Depreciation Expense for Asset Retirement Costs (Account 403.1); (d) Amortization of Limited-Term Electric Plant (Account 404); and (e) Amortization of Other Electric Plant (Account 405). Report in Section B the rates used to compute amortization charges for electric plant (Accounts 404 and 405). State the basis used to compute charges and whether any changes have been made in the basis or rates used from the preceding report year. Report all available information called for in Section C every fifth year beginning with report year 1971, reporting annually only changes to columns (c) through (g) from the complete report of the preceding year. Unless composite depreciation accounting for total depreciable plant is followed, list numerically in column (a) each plant subaccount, account or functional classification, as appropriate, to which a rate is applied. Identify at the bottom of Section C the type of plant included in any sub-account used. In column (b) report all depreciable plant balances to which rates are applied showing subtotals by functional Classifications and showing composite total. Indicate at the bottom of section C the manner in which column balances are obtained. If average balances, state the method of averaging used. For columns (c), (d), and (e) report available information for each plant subaccount, account or functional classification listed in column (a). If plant mortality studies are prepared to assist in estimating average service Lives, show in column (f) the type of mortality curve selected as most appropriate for the account and in column (g), if available, the weighted average remaining life of surviving plant. If composite depreciation accounting is used, report available information called for in columns (b) through (g) on this basis. If provisions for depreciation were made during the year in addition to depreciation provided by application of reported rates, state at the bottom of section C the amounts and nature of the provisions and the plant items to which related.
	A. Summary of Depreciation and Amortization Charges
Line No.	FunctionalClassificationAxis Functional Classification (a)	DepreciationExpenseExcludingAmortizationOfAcquisitionAdjustments Depreciation Expense (Account 403) (b)	DepreciationExpenseForAssetRetirementCostsExcludingAmortizationgOfAcquisitionAdjustments Depreciation Expense for Asset Retirement Costs (Account 403.1) (c)	AmortizationOfLimitedTermPlantOrProperty Amortization of Limited Term Electric Plant (Account 404) (d)	AmortizationOfOtherElectricPlant Amortization of Other Electric Plant (Acc 405) (e)	DepreciationAndAmortization Total (f)
1	Intangible Plant			20,508,961		20,508,961
2	Steam Production Plant	30,760,115	11,486			30,771,601
3	Nuclear Production Plant
4	Hydraulic Production Plant-Conventional
5	Hydraulic Production Plant-Pumped Storage
6	Other Production Plant	26,505,836				26,505,836
7	Transmission Plant	40,378,280				40,378,280
8	Distribution Plant	83,524,388				83,524,388
9	Regional Transmission and Market Operation
10	General Plant	(a) 21,748,967				21,748,967
11	Common Plant-Electric
12	TOTAL	202,917,586	11,486	20,508,961		223,438,033

B. Basis for Amortization Charges

	C. Factors Used in Estimating Depreciation Charges
Line No.	AccountNumberFactorsUsedInEstimatingDepreciationCharges Account No. (a)	DepreciablePlantBase Depreciable Plant Base (in Thousands) (b)	UtilityPlantEstimatedAverageServiceLife Estimated Avg. Service Life (c)	UtilityPlantNetSalvageValuePercentage Net Salvage (Percent) (d)	UtilityPlantAppliedDepreciationRate Applied Depr. Rates (Percent) (e)	MortalityCurveType Mortality Curve Type (f)	UtilityPlantWeightedAverageRemainingLife Average Remaining Life (g)
12	BaxterWilson Com 310.2	0.001	57 years		14.84	SQ	4 years, 8 months
13	BaxterWilson Com 311.1	0.731	57 years	38	8.32	R2.5	4 years, 7 months
14	Baxter Wilson Com 311	5.538	57 years	38	10.77	R2.5	4 years, 7 months
15	Baxter Wilson Com 312	2.546	57 years	38	12.65	R0.5	4 years, 6 months
16	Baxter Wilson Com 314	0.46	57 years	38	2.74	O1	4 years, 6 months
17	Baxter Wilson Com 315	5.104	57 years	38	12.61	R1.5	4 years, 6 months
18	Baxter Wilson Com 316	2.666	57 years	38	16.77	R1	4 years, 7 months
19	Baxter Wilson Un 1 311	6.608	57 years	38	12.12	R2.5	4 years, 7 months
20	Baxter Wilson Un 1 312	32.168	57 years	38	4.3	R0.5	4 years, 6 months
21	Baxter Wilson Un 1 314	37.925	57 years	38	13.66	O1	4 years, 6 months
22	Baxter Wilson Un 1 315	5.279	57 years	38	19.15	R1.5	4 years, 6 months
23	Baxter Wilson Un 1 316	0.303	57 years	38	19.56	R1	4 years, 6 months
24	Delta Common 310.2	0.001			1.87
25	Delta Common 311	0.04			1.18
26	Gerald Andrus 310.2	0.004	61 years		3.98	SQ	16 years, 6 months
27	Gerald Andrus 311	27.842	61 years	13	1.24	R2.5	16 years, 2 months
28	Gerald Andrus 311.1		61 years	13	0.79	R2.5	16 years, 2 months
29	Gerald Andrus 312	90.879	61 years	13	3.39	R0.5	15 years, 10 months
30	Gerald Andrus 314	35.451	61 years	13	3.26	O1	15 years, 7 months
31	Gerald Andrus 315	15.717	61 years	13	3.35		15 years, 11 months
32	Gerald Andrus 316	2.812	61 years	13	2.6	R1	16 years, 2 months
33	Gerald Pipelines 310.2	0.02	45 years		1.14		16 years, 7 months
34	Gerald Pipelines 311	0.375	45 years	13	1.94		16 years, 4 months
35	Gerald Pipelines 312	0.012	45 years	13
36	Independence Com 311	2.169	47 years	8	1.98	R2.5	11 years, 6 months
37	Independence Com 312	17.609	47 years	8	2.58	R0.5	11 years, 4 months
38	Independence Com 312.1	0.406	47 years	8	2.58	R0.5	11 years, 4 months
39	Independence Com 314	0.253	47 years	8	1.67	O1	11 years, 1 month
40	Independence Com 315	0.63	47 years	8	2.77	R1.5	11 years, 5 months
41	Independence Com 316	1.707	47 years	8	2.03	R1	11 years, 5 months
42	Independence Un 1 311	16.229	47 years	9	2.73	R2.5	11 years, 5 months
43	Independence Un 1 312	85.415	47 years	9	4.28	R0.5	11 years, 2 months
44	Independence Un 1 314	23.529	47 years	6	1.45	O1	11 years, 1 month
45	Independence Un 1 315	12.733	47 years	9	1.54	R1.5	11 years, 2 months
46	Independence Un 1 316	2.1	47 years	6	1.51	R1	11 years, 4 months
47	Independence Un 2 311	3.892	47 years	9	0.35	R2.5	11 years, 5 months
48	Independence Un 2 312	80.037	47 years	9	4.52	R0.5	11 years, 2 months
49	Independence Un 2 314	26.039	47 years	6	1.52	O1	11 years, 1 month
50	Independence Un 2 315	6.762	47 years	9	1.71	R1.5	11 years, 4 months
51	Independence Un 2 316	0.287	47 years	6	1.73	R1	11 years, 5 months
52	Natchez 310.2	0.04			4.93
53	Rex Brown Common 310.2	0.005	71 years		7.23		10 years
54	Rex Brown Common 311	0.104	71 years		5.29		10 years
55	Rex Brown Common 316	0.265	71 years		7.13		10 years
56	Rex Brown Unit 1 312	0.005			4.22
57	Delta Common 311_RES	2.403			10
58	Delta Common 312_RES	0.401			10
59	Delta Common 314_RES	0.019			10
60	Delta Common 315_RES	0.371			10
61	Delta Common 316_RES	0.205			10
62	Delta Unit 1 312_RES	0.266			10
63	Delta Unit 1 314_RES	0.164			10
64	Delta Unit 1 315_RES	0.258			10
65	Delta Unit 1 316_RES	0.057			10
66	Delta Unit 2 312_RES	0.261			10
67	Delta Unit 2 314_RES	0.179			10
68	Delta Unit 2 315_RES	0.189			10
69	Delta Unit 2 316_RES	0.091			10
70	Natchez 310.2_RES	0.023			10
71	Natchez 311_RES	0.655			10
72	Natchez 312_RES	2.285			10
73	Natchez 314_RES	1.509			10
74	Natchez 315_RES	0.703			10
75	Natchez 316_RES	0.26			10
76	Rex Brown Unit 1 311_RES	0.016			10
77	Rex Brown Unit 1 312_RES	0.079			10
78	Rex Brown Unit 1 314_RES	0.105			10
79	Rex Brown Unit 1 315_RES	0.022			10
80	Rex Brown Unit 1 316_RES	0.031			10
81	Rex Brown Unit 2 311_RES	0.033			10
82	Rex Brown Unit 2 312_RES	0.294			10
83	Rex Brown Unit 2 314_RES	0.196			10
84	Rex Brown Unit 2 315_RES	0.098			10
85	Rex Brown Unit 2 316_RES	0.033			10
86	Attala Common 341	6.314	35 years		3.33	SQ	17 years, 7 months
87	Attala Common 342	1.369	35 years		3.33	SQ	17 years, 7 months
88	Attala Common 343	0.274	35 years		3.33	R0.5	13 years, 5 months
89	Attala Common 344	0.613	35 years		3.33	L0.5	15 years, 2 months
90	Attala Common 345	1.471	35 years		3.33	L0	16 years
91	Attala Common 346	1.601	35 years		3.33	R0.5	13 years, 10 months
92	Attala Unit 1 341	9.951	35 years		3.33	SQ	17 years, 7 months
93	Attala Unit 1 342	2.148	35 years		3.33	SQ	17 years, 7 months
94	Attala Unit 1 343	46.373	35 years		3.33	R0.5	14 years
95	Attala Unit 1 344	44.797	35 years		3.33	L0.5	15 years, 2 months
96	Attala Unit 1 345	12.896	35 years		3.33	L0	15 years, 11 months
97	Attala Unit 1 346	0.909	35 years		3.33	R0.5	14 years, 2 months
98	Choctaw Unit 1 340.1	2.761
99	Choctaw Unit 1 341	18.843			4.55
100	Choctaw Unit 1 342	2.829			4.55
101	Choctaw Unit 1 343	208.856			4.55
102	Choctaw Unit 1 344	49.024			4.55
103	Choctaw Unit 1 345	20.741			4.55
104	Choctaw Unit 1 346	0.93			4.55
105	Hinds Unit 1 341	15.462	35 years		3.33	SQ	17 years, 7 months
106	Hinds Unit 1 342	0.196	35 years		3.33	SQ	17 years, 7 months
107	Hinds Unit 1 343	52.284	35 years		3.33	R0.5	14 years, 10 months
108	Hinds Unit 1 344	131.766	35 years		3.33	L0.5	15 years, 7 months
109	Hinds Unit 1 345	3.219	35 years		3.33	L0	16 years, 2 months
110	Hinds Unit 1 346	2.278	35 years		3.33	R0.5	14 years, 7 months
111	Hinds Unit 2 341	4.31			3.33	SQ
112	Hinds Unit 2 342	2.108			3.33	SQ
113	Hinds Unit 2 343	25.584			3.33	SQ
114	Hinds Unit 2 344	4.966			3.33	SQ
115	Hinds Unit 2 345	7.654			3.33	SQ
116	Hinds Unit 2 346	0.856			3.33	SQ
117	Solar Brookhaven 341	1.552	20 years		5	SQ	17 years
118	Solar DesotoCounty 341	1.416	20 years		5	SQ	17 years
119	Solar Hinds County 341	1.594	20 years		5	SQ	17 years
120	Transmission 350.2	83.165	75 years		2.62	S5	27 years, 6 months
121	Transmission 352	62.983	70 years	10	1.89	R3	51 years, 2 months
122	Transmission 353	708.018	55 years		1.83	R2	42 years, 5 months
123	Transmission 354	56.66	65 years	40	2.28	R4	30 years, 5 months
124	Transmission 355	485.534	60 years	85	3.45	R2	52 years, 5 months
125	Transmission 356.1	275.936	70 years	50	2.59	R1.5	56 years, 2 months
126	Transmission 356.2	6.265	70 years	50	2.59	R1.5	56 years, 2 months
127	Transmission 356.3	45.521	70 years	50	2.59	R1.5	56 years, 2 months
128	Transmission 357	0.001	60 years		1.66	S2	43 years, 11 months
129	Transmission 358	0.006	55 years		1.8	S2	39 years, 4 months
130	Distribution 360.2	4.632	75 years		1.27	S5	42 years, 11 months
131	Distribution 361	19.548	60 years	10	1.83	R4	43 years, 5 months
132	Distribution 362	391.499	70 years		2.06	R1.5	57 years, 1 month
133	Distribution 364	411.774	36 years	25	3.75	R0.5	28 years, 6 months
134	Distribution 365.1	445.408	45 years	25	3.57	O1	38 years, 5 months
135	Distribution 365.2	1.175	45 years	25	3.57	O1	38 years, 5 months
136	Distribution 365.3	55.021	45 years	25	3.57	O1	38 years, 5 months
137	Distribution 366	51.451	60 years	20	2.06	R2	50 years, 5 months
138	Distribution 367	103.371	60 years		1.64	R1	49 years, 5 months
139	Distribution 368.1	605.664	28 years	15	4.17	R1.5	20 years, 2 months
140	Distribution 369.1	136.301	40 years	25	3.29	R2	29 years, 10 months
141	Distribution 369.2	54.176	42 years	25	2.45	R2	31 years, 1 month
142	Distribution 370	6.263		5	3.26		3 years, 1 month
143	Distribution 370.1	0.025			3.26
144	Distribution 370.15	111.058	15 years		6.67	SQ	15 years
145	Distribution 371	41.775	25 years	5	2.24	L0	18 years, 11 months
146	Distribution 373	86.116	25 years	10	4.19	R1	17 years, 11 months
147	Distribution 373.2	0.034	30 years	5	3.44	R1.5	28 years, 11 months
148	RTO 382				20
149	General Plant 389.2	0.001	75 years		1.72	S5	50 years, 4 months
150	General Plant 390	113.147	55 years	10	2.28	R2.5	42 years, 2 months
151	General Plant 390.1	0.035	55 years			R2.5	42 years, 2 months
152	General Plant 391.1	1.028	15 years		6.67	SQ	13 years, 11 months
153	General Plant 391.2	19.031	5 years		20	SQ	3 years, 8 months
154	General Plant 391.3	0.372	15 years		6.67	SQ	12 years
155	General Plant 392	0.262	5 years		20	SQ	3 years, 5 months
156	General Plant 393	0.012			6.67
157	General Plant 394	7.492	15 years		6.67	SQ	13 years, 2 months
158	General Plant 395	4.412	10 years		10	SQ	8 years
159	General Plant 396	0.064			6.67
160	General Plant 397.1	21.335	10 years		10	SQ	7 years, 4 months
161	General Plant 397.2	6.67	10 years		10	SQ	7 years, 6 months
162	General Plant 398	1.676	10 years		10	SQ	7 years, 4 months
163	(b) Contra UA 391.1_RES	1.556			10
164	(c) Contra UA 391.2_RES	7.308			10
165	(d) Contra UA 391.3_RES	0.655			10
166	(e) Contra UA 392_RES	0.076			10
167	(f) Contra UA 393_RES	0.664			10
168	(g) Contra UA 394_RES	3.886			10
169	(h) Contra UA 395_RES	0.195			10
170	(i) Contra UA 396_RES	0.327			10
171	(j) Contra UA 397.1_RES	1.998			10
172	(k) Contra UA 397.2_RES	8.685			10
173	(l) Contra UA 398_RES	0.518			10

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2022

Year/Period of Report

End of:

2021

/

Q4

FOOTNOTE DATA

(a) Concept: DepreciationExpenseExcludingAmortizationOfAcquisitionAdjustments

Includes $3,207,943 of service company depreciation billing allocations.

(b) Concept: AccountNumberFactorsUsedInEstimatingDepreciationCharges